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Home My WebLink About203-027CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: LPP/SSV Returned to Service on CPAI Well 1C-174 on 11.20.22 Date:Monday, November 21, 2022 10:16:36 AM Attachments:image002.png image003.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Monday, November 21, 2022 6:41 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; NSK Operations Superintendent <n2073@conocophillips.com>; Braun, Michael <Michael.Braun@conocophillips.com>; Abbas, Sayeed <Sayeed.Abbas@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com> Subject: LPP/SSV Returned to Service on CPAI Well 1C-174 on 11.20.22 Good Morning Jim, The low-pressure pilot (LPP) on well 1C-174 (PTD# 203-027) was returned to service and removed from the “Facility Defeated Safety Device Log” on 11/20/2022 at ~8pm, as the well has been maintaining > 100psi on the injection tubing pressure since the offset producer was shut in late last week. The LPP had been defeated on 11/16/2022 after a significant injection pressure reduction (due to well communication with an offset producer) could not satisfy the LPP. This notification is in accordance with “Administrative Approval No. CO 406B.001.” Please let me know if you have any questions. Thank you, Will Parker Production Engineer – GKA (CPF1-West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Thursday, November 17, 2022 7:40 AM To: 'Regg, James B (DOA)' <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; NSK Operations Superintendent <n2073@conocophillips.com>; Braun, Michael <Michael.Braun@conocophillips.com>; Abbas, Sayeed <Sayeed.Abbas@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: Defeated LPP/SSV on CPAI Well 1C-174 on 11.16.22 The low-pressure pilot (LPP) on well 1C-174 (PTD# 203-027) was defeated yesterday 11/16/2022 at ~8pm AKST, when the wellhead injection pressure dropped below LPP setpoint (100psi) as a result of assumed communication with an offset producer. We plan to leave the injector online as we conduct interference diagnostics on the nearby producer (1C-178) that we assume is in communication with this injector. The well is currently injecting at ~850BWPD and wellhead pressure is at 75psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the “Facility Defeated Safety Device Log.” The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with “Administrative Approval No. CO 406B.001.” Please let me know if you have any questions. Thank you, Will Parker Production Engineer – GKA (CPF1-West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Defeated LPP/SSV on CPAI Well 1C-174 on 11.16.22 Date:Friday, November 18, 2022 9:46:16 AM Attachments:image002.png Kuparuk River Unit 1C-174 (PTD 2030270) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Thursday, November 17, 2022 7:40 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; NSK Operations Superintendent <n2073@conocophillips.com>; Braun, Michael <Michael.Braun@conocophillips.com>; Abbas, Sayeed <Sayeed.Abbas@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: Defeated LPP/SSV on CPAI Well 1C-174 on 11.16.22 The low-pressure pilot (LPP) on well 1C-174 (PTD# 203-027) was defeated yesterday 11/16/2022 at ~8pm AKST, when the wellhead injection pressure dropped below LPP setpoint (100psi) as a result of assumed communication with an offset producer. We plan to leave the injector online as we conduct interference diagnostics on the nearby producer (1C-178) that we assume is in communication with this injector. The well is currently injecting at ~850BWPD and wellhead pressure is at 75psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the “Facility Defeated Safety Device Log.” The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with “Administrative Approval No. CO 406B.001.” Please let me know if you have any questions. Thank you, Will Parker Production Engineer – GKA (CPF1-West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-174 KUPARUK RIV U WSAK 1C-174 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 1C-174 50-029-23140-00-00 203-027-0 W SPT 3709 2030270 1500 672 674 670 669 4YRTST P Austin McLeod 5/13/2022 Monobore. MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U WSAK 1C-174 Inspection Date: Tubing OA Packer Depth 1320 1910 1890 1880IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220514075807 BBL Pumped:1.2 BBL Returned:1.1 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.14 09:26:35 -08'00' KRJA !C-I?4 Regg, James B (CED) PTS Ze3D h'70 From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Monday, June 7, 2021 2:30 PM ILCAr/ (0/7'�Z r To: Regg, James B (CED) C Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Autry, Sydney; Braun, Michael (Alaska) Subject: LPP/SSV Returned to Service on CPAI Well 1C-174 on 6/2/2021 Jim, The low pressure pilot (LPP) on well 1C-174 (PTD# 203-027) was returned to service and removed from the "Facility Defeated Safety Device Log" on 6/2/2021, after the well was shut-in. The LPP had been defeated on 3/23/2021 when the well was brought back online after an extended downtime. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Thank you, Toon Toon Changklungdee WestSak Production Engineer office: (907)659-7234/(907)265-1375 Cell: (303) 564-7586 Prb 7�130Z70 Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> j� Sent: Tuesday, March 23, 2021 7:42 PM ' `gjg1 �(Z41 2Z72, To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Braun, Michae (Alaska); Thomson, Stephanie; NSK West Sak Prod Engr; Lyons, Kelly A; NSK West Sak Prod Engr Subject: Defeated LPP/SSV on CPAI Well 1C-174 on 3/23/2021 Jim, The low pressure pilot (LPP) on well 1C-174 (PTD# 203-027) was defeated today, 3/23/2021, when brought online after an extended downtime. The well is currently injecting at 410 BWPD with a wellhead pressure of 20 psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Thank you, Toon Toon Changklungdee / Kelly Lyons CPF1 / WestSak Production Engineer Office: (907) 659-7234 Cell: (303) 564-7586 Pager: (907) 659-7000 pp 497 K' - IC- r74 - Pm ze 3027 0 Regg, James B (CED) From: NSK West Sak Prod Engr <nl638@conocophiIIips.com> Sent: Saturday, December 7, 2019 7:54 AM` I-ZICO`l S To: Regg, James B (CED) % Z Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; Well Integrity Compliance Specialist CPF1 & 2; NSK Optimization Engr; CPF1 &2 Ops Supt; Fox, Pete B; Braun, Michael (Alaska); Mowrey, Andrew F Subject: LPP/SSV Returned to Service on CPAI well 1C-174 - 12/7/2019 Jim, r/ The low pressure pilot (LPP) on well 1C-174 (PTD# 203-027) was returned to service and removed from the "Facility Defeated Safety Device Log" today, 12/7/2019, after the well was shut-in. The LPP had been defeated on 11/1/2019 when the wellhead pressure had fallen below the LPP setpoint. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 9497 MEMORANDUM State of Alaska Permit Number: 203-027-0 Alaska Oil and Gas Conservation Commission TO: Jim Regg / 1q P.I. Supervisor C Cry i��/51 t l 11 1 DATE: Thursday, November 14, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. IC -174 FROM: Brian Bixby KUPARUK RN U WSAK 1C-174 Petroleum Inspector Well 1C-174 Ste: Inspector W' Reviewed By: 1 3709 P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK IC -174 API Well Number 50-029-23140-00-00 Inspector Name: Brian Bixby Permit Number: 203-027-0 Inspection Date: 11/10/2019 Insp Num: mitBDB191111161543 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1C-174 Type Inj W' TVD 1 3709 Tubing I 16 16 - m I9 - PTD 2030270 Type Test SPT Test psi 1500 IA 560 1800 - 1720 1710 ' BBL Pumped: zs BBL Returned: 2.5 OA Interval 4YRTST P/I'i P Notes: There is no OA. This is a monobore completion. Thursday, November 14, 2019 Page 1 of I �< 2N IC -1-74 Regg, James B (CED) r N Z6:302"70 From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, November 1, 2019 11:58 AM 7 To: Regg, James B (CED) 1� _� Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1 &2 Ops Supt; Braun, Michael (Alaska); Fox, Pete B; CPF1 Prod Engr; NSK Optimization Engr Subject: RE: Defeated LPP/SSV on CPAI well 1C-174 on 11/1/2019 Jim, The low pressure pilot (LPP) on well 1C-174 (PTD #203-027) was defeated today, 11/1/2019. Injection pressure declined since the well was returned to service following remediation well work. The well is currently injecting 510 BWPD and wellhead pressure is 37 psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Best Regards, Danila Shutemov / Toon Changklungdee / Marina Krysinskil WestSak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 16ett (C - ('74 Regg, James B (CED) r) U302,:-71 From: NSK West Sak Prod Engr <n1638@conocophillips.co Sent: Wednesday, October 23, 2019 1:01 PM j To: Regg, James B (CED) ( �N fCIM (Ci Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; Braun, Michael (Alaska); Fox, Pete B; CPF1 Prod Engr; NSK Optimization Engr Subject: Defeated & Reinstated LPP/SSV on CPAI well 1C-174 on 10/23/2019 Jim, M The low pressure pilot (LPP) on well 1C-174 (PTD #203-027) was defeated today, 10/23/2019, after the well was returned to service following remediation well work. LPP was reinstate_da_nT_re_tu_rnQ to normal after appr. 3 hours of initial fill -up. Drill site was continuously manned during that period. The well is current y infecting 119 BWPD and wellhead pressure is 502 psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." / Please let me know if you have any questions. Best Regards, Danila Shutemov / Toon Changklungdee / Marina Krysinskil WestSak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate E Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ eforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: RPPG MBE TRTMT❑+ 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development ❑ Exploratory ❑ 203-027 3. Address: P. O. BOX 100360, Anchorage, Stratigraphic❑ Service E] 6. API Number: Alaska 99510 50-029-23140-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 26649, ADL26638 KRU IC -174 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12,485 feet Plugs measured 8305, 10909 feet true vertical 3,876 feet Junk measured None feet Effective Depth measured 12,483 feet Packer measured 7,021 feet true vertical 3,676 feet true vertical 3,706 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 83 feet 16 110' MD 110' TVD SURFACE 7,140 feet 9 5/8 " 7,169' MD 3725' TVD LINER 5,476 feet 51/2" 12,485' MID 3876'TVD RECEIVE® OCT 17 zdls Perforation depth: Measured depth: 7333-12399 8215-8220 10819-10824 True vertical depth: 3748-3865 3806-3806 3827-3827 AOGCC AOGCC 113..,,7709' Tubing (size, grade, measured and true vertical depth) 4.5" L-80 7,063' MD TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER ZXP LINER TOP PKR 7,021' MD 3,706' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN _ _ _ _ 14. Attachments (required per 20 AAC 25.070, 25.071, & 26.2 83) 15. Well Class after work: Daily Report of Well Operations 121 Exploratory ❑ Development ❑ Service 21 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ M WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-361 Authorized Name: John Peirce contact Name: John Peirce Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com� Authorized Signature: Date: x©/16 /19 Contact Phone: (907) 265-6471 Form 10404 Revised 4/2017 VTL to/2z/ig Submit Original Only r//9 RBDMS L*u OCT 2 12019 , t KUP INJ WELLNAME 1C-174 WELLBORE 1C-174 CanocoP�1(li(1 $ Well Attributes Max Angle & MD TD 1" I W Il �reppNUV/I Wellbore 6ptYs I clf) 1,1171) pnl5.1ND"B1 Ad5M8.pG. LLNFSTaSAK I o3lmm� I1n11 �c �� NIPPLE ,C-174.1wldradn Gee PM Last Tag vwbodsne,nahilaweO Annotation D.P.Pool End Dole W¢61nre Last Moa By ....................._................................... RANGER, Lb A and ^^cono"ucioa; zi.oi foo NIPPIE, 489.3 GLS LIFT; 2,W15 NIPPLE: oacer7 LOCATOR: TOM.8 6ErLLA66Y', 704a 6' 6uRFACE. 28]-7 UPD� APERF: dZEC1,aoo_� PLUG, 83051-4CSG ♦ G1.Ts;7.G.lL.NGd CMT', 10.735.0 MERF; fO.etR0.148]a0 c.m.asoz: 1lx73e.Dmiet- _ PLUG; m,sro1 �I LINER?.N3.L's"pa.1-+ ............... _ - _ Last Tag: 12,391.0 10242004 lC-174 V Conversion Last Rev Reason Annotetmn Em Dara vai Last Moa By REV REASON. SET IBP, APERF FORHPPG 9/192019 1C-1]4 eappleh Casing Strings Crime Oesorlpllon OD (n) ID lint ToIDKE) at Depth (XKGI Bat map.- mp)... WOLen P. -IG eatle Top TLreatl GOING CONDUCTOR 16 15.06 2Z0 1100 110.0 6250 H40 WELDED Casino Dssctlplbn OD (Int ID (int Top lnKBl SH DapM IKKBI Set Oepm (TVDL.. wulnn p... Graae Top TM1reatl SURFACE 9518 883 28.) ],168.9 3,]24.9 40.00 LEO BTCSAD Casing Description OD (in) ID (In) Tete IXKB) BH Dopar MKD) 6N Depth RVU, line l... G2tle Top Tbeatl LINER 512 4.95 7,0094 12,48E0 3,8762 15.50 LEO Hytlril511 Liner Details rvominallD Top lnlcel Tate MD) moil TOP and f) team Des Com Nn) 7.00F4 3,704.0 82.58 NIPPLE LIFT NIPPLE WJUNKBONNET 3.750 7,021.4 3,]05.8 III PACKER BAKER ZAP LINER TOP PACKER WMR PROFILE 6.290 7,0350 3,]0].3 82.53 NIPPLE RB NIPPLE 6.188 7,037.4 3,707.6 82.52 HANGER BAKER FLEX LOCK HYO LINER HANGER 6.310 7,047.6 3,709.0 82.51 XO BUSHING CROSSOVER BUSHING T'x5.5" 4.890 7,050> 3,7094 82.51 SBE BAKER SEAL BORE EXTENSION 4750 Tubing Strings Tubing Description siring Ma... l0 (Int Top IRKBI S.1 .am an- set Death ITVDI (... Iva I GmGe Top Connection TUBING 41/2 3.95 22.8 7,0630 3,7110 12.60 L-80 NSCT Completion Details - TOP mCI Tote and Nominal Tampons I Inxal D Itm Dee Co. ID anI 22.8 22.8 6.60 HANGER VETCO GRAY TUBING HANGER 4566 4986 4976 826 INIPPLE CAMCO DS NIPPLE es/NO GO PROFILE 3812 72993 3,544.2 68.38 NIPPLE CAMCO DB NIPPLE wNO GO PROFILE 3750 3,]08.6 82.51 LOCATOR BAKER G-22 LOCATOR 387 ],0450 3]057 62.51 IbLALAbbYBAKER GBH -22 SEAL ASSEMBLY 3.870 Wire Other In Hole (line retrievable Plugs, valves, pumps,. fish, etc.) T.RV I Tasman IDP ME) mp to 11 i o"Com Ran Date ID (in) 8,305.0 3]996 93.59 PLUG 25"BAKER IBP 9/1012019 0.000 11,7,735.03,831.1 93.07 CMT CEMENT RETAINER 5152009 4.580 10,909.0 3,821.6 9342 PLUG 3.5"TTS IBP 5142009 0.000 PATCH Instal Sleeve from bottom of hanger to below suace 1/1/2011 Casing pup collar (5'), bands made from 10"X65 500 wall pipe, sleeve made from 12"X6538] wall pipe Perforations & Slots Top (XKB) Bim lrfKBl Topli IflKBI arm (11N61KE) Linketl Zane pa@ snot Dana I+M1O[stt[ 1 Tape Co. 7,333.0 12,399.0 3,7476 3,864.8 W D,W C, WE 5,1C -V4 3x302003 990 SLOTS Alternating 1311 501[111 SIDXed UNDULATING LINER; .02"x1.5" slots 812158 8,2200 3,805.9 J, 805.5 WS B. 1C-174 911912019 6.0 APERF .38" N210 PF PHASE AS' PENETRATION HMX PERF GUN. 10,819.0 10,824.0 LI 3,826.6 3,8263 WSC,1C-1]4 51412009 8.0 APERF -SUZU"MMUll 20 BBLS ULTRA LITECRETE CEMENT THROUGH RETAINER w/16 bbls BEHIND PIPE Cement Ss queeze Top (Me) atm loom TOP mol Rbn mD) (nKB) IXKeI Dea sten Dale Co. 10,136.0 1Q9p9.0 3,8310 I 3,821.6 CEMENT SW WW20D9 PUMPED 20 BELS ULTRA LITECRETECEMENT THROUGH RETAINER SET 11110735 CTMD Mandrel Inserts sl all N Tap lflKSl Top mDl ItIXB) Make Matlel OD lin) Sery Valve Tyce LahM1 TYFe -a to. lint TRO Run Ip11 Run Cafe Co. 1 2,504.5 1,9205 CAMCO KBG-2 1 GAS LIFT OMV BK5 O.L00 OD 5/102003 Notes: General &Safety End Data Annmaflon 101162019 NOTE: VIEW SCHEMATIC WIAlaska SchemafiC108 101162019 IND I E: 9126119- FUIlbore RPPG job pumped 7800 JIM, of REPO to D MBE 1 C-174 RPPG MBE TREATMENT DTTM JOBTYP SUMMARYOPS START 9/10/19 MISC, SET BAKER 2.50" IBP AT 8305' CTMD, RIH WITH DUMMY PERF GUN CAPACITY DRIFT (3.62" ODX10') DOWN TO 8250' CTMD, F/P TBG TO 5000' CTMD, SUSTAINMENT JOB IN PROGRESS. 9/19/19 MISC. RIH WITH 3.38" 6 SPF 3412 PF HMX 14.2 GM, .64" ENT HOLE 4.5" CAPACITY PENETRATION GUN DOWN TO IBP AT 8305', PU TO 8220' CTMD, DROP SUSTAINMENT .5' BALL, FIRED 5' GUN. OOH BALL RECOVERED, PERFORM WEEKLY BOP TEST. WELL READY FOR RPPG JOB. 9/26/19 MISC. PUMPED FULLBORE RPPG TO TARGET MBE (ESTIMATED 8200'MD): CAPACITY IBP IN WELL AT 8305' CTMD. PUMPED 715 -BBL TREATMENT SUSTAINMENT INCLUDING 135 -BBL 2% KCI PRE -FLUSH, FOLLOWED BY 457 -BBL SLURRY CONTAINING KCI PLUS 7800# RPPG PRODUCT. DISPLACED SLURRY TO MBE WITH 92.5 -BBL KCI AND 41 -BBL DIESEL FP. GAINED APPROXIMATELY 950 -PSI NET PRESSURE DURING TREATMENT PUMPING 1.5-4.0 BPM. 203©27 31138 WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Injection Profile 2) Signed Print Name: ProActive Diagnostic Services, Inc. Attn: Diane Williams 130 West International Airport Road Suite C Anchorage, AK 99518 Adsa nchorageCcbmemorvlog.com 18 -Aug -19 1C-174 CD RECEIVF,r,D AUG 2 9 2019 AOGCC 50-029-23140-00 Date : q q PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245.8952 E-MAIL: PDSANCHORAGEO.MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM Mips readcasedhole-my.sharepoint. wm/personal/diane_williams readcasedhole com/DocumentsD DmJAchives/MagerTemplateFiles/Templates Distrib.to. TansmittalSheets/ConocoPhillips_T...mitdocn THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1C-174 Permit to Drill Number: 203-027 Sundry Number: 319-361 Dear Mr. Peirce: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a ogcc.al aska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 46�� Daniel T. Seamount, Jr. Commissioner DATED this { - day of August, 2019. IGrW 61619 �BdMS�� AU6 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ',11 e E IVED AUG 0 6 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate O Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG MBE TRTMU 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service p 203-027 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23140-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?' N/A B 6 1 Q Will planned perforations require a spacing exception? Yes O No [71 KRU 1C-174 9. Property Designation (Lease Number): 10. Field/Pool(s): r ADL 25649, ADL 25638 Kuparuk River Field / West Sak Oil Pool a 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12,485' 3,876' 12483 38761200psi 10736 NONE Casing Length Size MD TVD Burst Collapse Conductor 83' 16" 110' 110' Surface 7,140' 95/8 7,169' 3,725' Liner 5,476' 51/2 12,485' 3,876' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7333.12399, 10819.10824 3748-3865, 3827-3827 4.500" L-80 7,045' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER = BAKER ZXP LINER TOP PACKER 7021 MD and 3706 TVD SSSV =NONE WA 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service O 14. Estimated Date for 9/1/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ El WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com // Contact Phone: (907) 265-6471 Authorized Signature: ,� r fL.0 G✓ � — � I S�� Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No Er ;gpMS�UG 1 6 2019 Spacing Exception Required? Yes ❑ No 1111`1Subsequent Form Required: D ¢ D-7 APPROVED BY� Approved by: COMMISSIONER THE COMMISSION Date Jj4/l S 44c, NAL Submit Form and 20-403 Re sed a/z0n Approved application is valid for 12 mon hs from" tlie-0'dte of approval. Attachments in Duplicate Reformed Polymer Particle Gel Treatment of B Sand MBE from 1C-174 to 1C-178 1C-174 horizontal undulating injector (HUI) was drilled and completed in April 2003 with 4.5" tubing and 5.5" slotted liner. A West Sak D Sd Matrix Bypass Event occurred 3-8-07 between 1C-174 and 1C-178 producer. A 9-7-08 IPROF verified the MBE was deeper than 11400' RKB with estimated location at 11530' RKB to D Sand. On 5/5/09, 20 bbls of 8.6# Ultralight Cement Plug was pumped through a Cement Retainer set at 10735' RKB to isolate the MBE to 1C-178. This treatment allowed 1 C-174 to return to service until a new MBE became evident in early 2018 from 1 C-174 to 1 C-178. An (PROF of 4/15/18 showed a possible MBE forming at 8100' RKB in a B Sand section of 1C-174. This feature took some split of total injection but it was not robust enough to treat yet with RPPG. A new IPROF of 7/19/19 now shows a mature B MBE exists at 8200' taking a majority of total injection. It has been verified that this MBE is in direct communication to 1C-178 horizontal producer. Per this procedure, an Inflatable Bridge Plug will be set in 1C-174 at 8305' RKB (target) in 5.5" Liner at the middle of a 128' section of blank liner, then a 5' perforation interval will be shot at 8210 - 8215' RKB (target) in a slotted liner joint near the MBE at 8200' RKB. Next, a fullbore RPPG job will be pumped to the B MBE, and then 1C-174 will be returned to injection to verify the MBE is sealed. Procedure Coil Tubing: 1) RIH with 2.50" OD Inflatable Bridge Plug on CT. Set IBP in blank 5.5" Liner section at -8305' RKB 2) RIH with 3.375" OD x 7' OAL Perf Gun on CT. Perf 5' OAL interval at -8215 - 8220' RKB (target), at 6 spf, 60 deg phasing, to provide large hole perforations of 0.5 - 0.75" diameter in 5.5" liner to enable easy RPPG slurry passage to the B MBE. POOH with pert gun. Verify all shots fired. 3) Pumping: Put 1C-174 on injection at 500 - 1000 BWPD at 6 - 12 hours before RPPG job, to start displacing gas head & Diesel FP from wellbore to B MBE, to ensure that the MBE is open, and that the well becomes liquid packed and free of hydrocarbon contaminants that can inhibit RPPG swelling and crosslinking. RU Mixing Van & pumping equipment. When ready to pump RPPG job, SI water injection to 1C-174 and swap to fullbore pumping 1 wellbore volume (135 bbls to MBE) of 2% ultraclean KCL Brine into 1C-174, followed by RPPG slurry at steady -2.4 bpm by adding 1 - 4 mm mesh RPPG to ultraclean 2% KCL Brine to make slurry concentration at 0.75 ppg added (target), and to place swelling RPPG into MBE within an hour. Continue pumping slurry -2.4 bpm at 0.75 ppg concentration until WHIP reaches 800 - 1000 psi, then swap from RPPG slurry to pumping 92 bbls 2% KCL Brine -2.4 bpm, followed by 41 bbls Diesel FP at -2.4 bpm to 2000' TVD, followed by Shutdown. Wait 48 hours for RPPG to fully swell and crosslink in the MBE to form a rigid amalgamated mass of non -flowing crosslinked gel before returning 1C-174 to injection or 1C-178 to production. 4) Coil Tubing: If post -MBE treatment evaluation indicates B MBE is sealed: RIH w/CT & pull IBP at 8305 RKB If post -MBE treatment evaluation indicates an MBE retreatment is needed, the IBP will be left set KUP INJ ConowPhillipsw.0 AHribates e' Name Alaska. Inc.. IQ WEST SAK NIPPLE WELLNAME 1C-174 NJ WELLBORE 3369 1C-174 1cn4, 79a'A19 ¢axsz n4 Last Tag vanew Ov^,4olacWll Annotation wpM IKKO) EM Da@ WNIe"' Lastmoo By ............. ......................... ........ ... .......__..._........................... Last Tap: 12.3910 102412004 1C-174 Conversion HANGER; 728 Last Rev Reason Annotaue' End Dab WeIIEon LutMWay ev easom. ET -L Ka FLOW 1HRUSUB qT R D 11/1312011 1C-174 preplan CQY DDEBI 27,011 &A (2) NIPPLE', 4898 Casing Strings castor; Descapeon 00 (In) ID lot Top InMBI Set DepM lnMm) fill D.M., TV01--WULen {I... Grant Top Thread CONDUCTOR 16 1506 270 110.0 110.0 8250 H-00 WELDED Lamm Dasmidmon OOIm, Iefin) ToplKKel .DepM 11M8I BN put lTVOI... It T"ThrW Janata SURFACE518 8.83 287 7.168.9 3,724.9 40.Dp L-80 BTC -MD G9i LIFT; ao.a Pals Descrlgnn ODlinl IN I'mI rap past 6M poplh lnMBl 6N peps ITVOI--Pup,m II_.sraEe Top Thread LINER 5112 495 7,0094 12,485.0 3,876.2 1550 L-80 Hydril 511 I "IPP`rla�7 Liner Details Nommel ID Top("") Top ND, Masi Tap Incl l•) Rm Cls core art 7,0094 ,)04.0 8256 NIPPLE LIFT NIPPLE wOUNK BONNET 3750 LacnroR; lou.9 7,021.4 3,7056 82.96 PACKER BAKER ZXP LINER TOP PACKER WHIR PROFILE 6.290 7,035.0 3.7073 82.53 NIPPLE RS NIPPLE 6.188 1,03.4 707682.52 HANGER BAKER FLEX LOCK HYD LINER HANGER 6310 1,047.6 3,709.0 82.51 XO BUSHING CROSSOVER BUSHING 7"x5.5" 4.890 SEALAs6Y, 70m 6 1,0507 3.7094 82.51 SBE BAKER SEAL BORE EXTENSION 4.750 Tubing Strings Tumn...... ipaon 61ane ma... nTop lnXa) sM 0ewn Ix. 6ero.pM RNIB 1... wylbin) Gnee rop connection 113D91,51 TUBING 4112 228 1,0630 37110 1260 L-80 NSCT Completion Details SURFACRMF716119� Top N01 Topincl Nominal Top MKB) 111KBI (°I Item Des Com ID{int 22.8 22.6 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 498.6 497.6 8.26 NIPPLE CAMCO DB NIPPLE aNINO GO PROFILE 3812 6299.1 3546.2 68.)0 NIPPLE CAMCO DB NIPPLE w1 NO GO PROFILE 3750 1,0449 3108.6 82.51 LOCATOR BAKER G-22 LOCATOR 3815 7,045.6 3.108 ) 82.51 SEAL ASSY BAKER GBH22SEAL ASSEMBLY 3610 Other In Hole (Wirellne retrievable plugs, valves, pumps, fish, etc.) T,KKNDITop;nd TaP MIK 8)Dee Com Run Date HD (in) 107350 3,831.1 93.01 CMT Retainer EMENT RETAINER 5152009 1 4.580 10,8 0 3,82161 93.42 PLUG 35"TTS IBP 9142009 I 0000 CSG PATCH Instill leave mDonomo radial, t0-,?,wsulfate 1/12011 casing pup collar (5'), Woods made from 10'X65500 wall pipe, sleeve made from 12'X65 787 wall pipe _ Perforations & Slots shw pens Toppond El plebs Top MEM BIMIN I deal fitl(eI LmkeO Zane rah I Type Com 1,3330 12,399.0 3,747.8 38648 WS 31302003 99.0 SLOTS temahng oll' WS B, 1C-174 Stoned UNDULATING LINER: 02'x15"aloe 10,8190 10.8240 3,828.8 3, .3 W ,1 -1 )d 9142000 6.0 APERF SO 20 BELLS ULTRA THROUGH RETAINER THROUGH RETAINER w116 ODIs BEHIND PIPE 1 Cement Squeezes sLors: [avalzsae.o� rovlrvDl elm NOI Top ul arm(nKB) (Mood (KKD) Oea Sbrt Dah Co. 10736.0 10,909.0 3,8310 3,621.6 Cement SOZ 952009 PUMPED ZU bull ULTRA UiFumETE CEMENT THROUGH RETAINER SET @ 10735 CTMD Mandrel Inserts e, an Per MKB N To p ) TO"no)" IrtKBI Make steelOp11n) 6m Velye Type lath type pael9rte lin) TRO Run (poi) Run rom Cam 1 2,504.5 19205 CAMCO KBG-2 1 GAB LIFT DMY BK -5 0.000 0.0 511012003 CMTRNW;10,7350 Notes: General & Safety P. rah Anro n APERF', 1a8180-1aeb0 6/92009 NOTE VIEW SCHEMATIC w/Alest" Scloco 9.0 c.m.maDz: taTx.pnKe PLUG: 10,900.0 r LINER709.4-124aS.0� Kitt ( c - Q 4 - PT -h ZO302-To Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophilIips.com> Sent: Friday, July 5, 2019 4:04 PM �� ?ICq To: Regg, James B (CED) 1 Cc: Fox, Pete B; Braun, Michael (Alaska); CPF1 ead echs; CPF1 Ops Supv; CPF1&2 Ops Supt; Mowrey, Andrew F Subject: LPP/SSV Returned to Service on CPAI Well 1C-174 Jim, The low pressure pilot (LPP) on well 1C-174 (PTD# 203-027) was returned to service and removed from the "Facility Defeated Safety Device Log" today, 7/5/2019, after the well was shut in following performance diagnostic. The LPP had been defeated since 6/19/2019, after the well was returned to service to diagnose offset wells performance. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Thank you, Toon Toon Changklungdee / Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 P'M 2,03Oz-1 Q Regg, James B (CED) From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Wednesday, June 19, 2019 6:57 AM To: Regg, James B (CED) Cc: Fox, Pete B; Braun, Michael (Alaska); CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; Mowrey, Andrew F Subject: Defeated LPP/SSV on CPAI well 1C-174 on 6/19/2019 Jim, The low pressure pilot (LPP) on well 1C-174 (PTD# 203-027) was defeated this morning, 6/19/2019, after wellhead pressure fell below the LPP setpoint. The well is currently injecting at as wellhe-a-d-injection pressure of 423 psi and a rate of 1334 BWPD. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 4497 .2& IC- I-74- . -74. • ZC36i7c Regg, James B (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> J Sent: Wednesday, May 30, 2018 8:40 AM Kyr , /1 To: Regg,James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA);Wallace, Chris D (DOA) Subject: Recent MIT forms Attachments: MIT KRU 1C-10 05-29-18.xlsx; MIT KRU 1C-174 05-29-18.xlsx Hello— Attached, please find 10-426 forms for recent MITs completed at KRU. Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 crowJUN 06Z1l$ 1 0 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaa c(Oalaska.aov. AOGCC.Insoectorsaalaska.00v phoebe.brooks@alaska.pov chris.wallace(aialaska.aov OPERATOR: ConocoPhillips Alaska Inc, �y 51•31 I.G FIELD/UNIT/PAD: Kuparuk/KRU/1C Pad DATE: 05/29/18 OPERATOR REP: Beck/Duffy AOGCC REP: Non Witnessed Well 1C-174 Pressures: Pretest Initial 15 Min, 30 Min. 45 Min. 60 Min. PTD 2030270_ Type Inj N - Tubing 1100 ' 1100 • 1100 - 1100 Type Test P Packer TVD 3709 ' BBL Pump 5.6 - IA 13 1900 " 1840 ' 1815 Interval 4 Test psi 1500 BBL Return 3.4 ' OA NA NA NA NA Result P Notes: Not Witnessed-Well is shut in Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) 2018-0529_MIT_KRU_1C-174 • • 20 3027 WALL LOG2 9 1 9 4 TRANSMITTAL E E PROACTIVE DIAGNOSTIC SERVICES, INC. APR } 6 i AO G CC To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C SCAN Anchorage, AK 99518 Fax: (907) 245-8952 1) Injection {rofile 15-Apr-18 1C-174 CD 50-029-23140-00 2) Signed : �� Date : Print Name: . PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE(G.MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\Transmittal Sheets\ConocoPhillips_Transmit.docx • • 203027 WELL LOG 2 9 1 9 3 TRANSMITTAL PROACTIVE DiAgNOSTIC SERViCES, INC. RECENEP APR l62018 To: AOGCC Natural Resources Technician AOGCC 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 SCANNEV Fax: (907) 245-8952 1) Injection Profile 09-Apr-18 1C-174 CD 50-029-23140-00 2) Thr2 Signed : Date : ` 301 Print Name: M_ • PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D\Achives\MasterTemplateFi les\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx • 1c2ct. i C Regg, James B (DOA) 2'30 Z7a From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Saturday, December 9, 2017 12:49 PM �,J To: Regg,James B (DOA) 1 ' i t 7 Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt;Autry, Sydney;Targac, Gary; Fox, Pete B; Sudan, Hari Hara Subject: LPP/SSV Returned to Service on CPAI well 1C-174 - 12/9/2017 Jim, The low pressure pilot (LPP) on well 1C-174(PTD#203-027)was returned to service and removed from the "Facility Defeated Safety Device Log" today, 12/9/2017, after the well was shut-in. The LPP had been defeated on 12/6/2017 when the wellhead pressure had fallen below the LPP setpoint of 300 psi.This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Marina Krysinski/ Mitch Autrey West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 SCANNED ?, 1 • • Ke, is- 'p74 i -3 c02_70 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Thursday, December 7, 2017 7:37 AM To: Regg,James B (DOA) c'lq 14*7 Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt;Autry, Sydney; Targac, Gary; Fox, Pete B; Sudan, Hari Hara Subject: Defeated LPP/SSV on CPAI well 1C-174 on 12/6/2017 Jim, The low pressure pilot (LPP) on well 1C-174(PTD#203-027)was defeated yesterday, 12/6/2017, after wellhead pressure fell to below 300 psi.The well is currently injecting at a wellhead injection pressure of 93 psi and a rate of 680 BWPD. The LPP and surface safety valves(SSV) have been tagued and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Marina Krysinski /Mitch Autrey West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 SCANNED , 1 ) ) Image Project Well History File Cover Page XHVZE This page identifies those items' that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. a,Q3 - OJ. ~ Well History File Identifier Page Count from Scanned File: 7 '=)- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO Helen\Maria'1 Date:.Ç, '¡Io/ OS; /5/ vvtP If NO in stage 1 page(s) discrepancies were found: YES NO Organizing (done) D Two-sided 1111111111I "'11111 RESCAN vÄOlor Items: co ~reyscale Items: '. , ~oor Quality Originals: D Other: DIGITAL DATA D Diskettes, No. D Other, No/Type: NOTES: BY: HelenCMaria ) Project Proofing BY: Helen f; Maria) Scanning Preparation BY: Helen ~ :J_ X 30 =00 Production Scanning Stage 1 BY: Stage 1 BY: Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: ~escan Needed i OVERSIZED (Scannable) o Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: o Other:: 1 Date:6' ¡G' ÐS /5/ mP DateS I b ~5 /5/ M-'J + I '-I- = TOTAL PAGES Zlf (6ount doe 3 n~ · \clude cover 5 eet) VIA, J Date. \'7 Ib ()t,.-t;- 151 I r ~ I Date: 151 11I111/ I I II II Date: 151 Quality Checked III II 1111/11 II 11/11 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 26, 2011 RECEtVED Commissioner Dan Seamount NOV 0 2 201 Alaska Oil and Gas Commission , 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Alaska Oii & Ga8 Cons. Commission Commissioner Dan Seamountt 2, 3` C) s - 7 1 G Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 9/11 and, 9/12, 2011. The corrosion inhibitor /sealant was pumped 10/15, 10/16,.10/17 and, 10/18, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. S i n c e r e l y , , + l ti . , i ii r 1 3 ZO1• /7 w Y? Martin Walters ConocoPhillips Well Integrity Projects Supervisor • S ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off 9 Y , p Report of Sundry Operations (10 -404) Kuparuk Field Date 10/26/11 1A,1B,1C,1D, 1E & 11' PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement' pumped cement date inhibitor sealant date ft bbls ft gal 1A -22 50029221270000 1910030 SF N/A 18" N/A 2.55 10/18/2011 WSW -01 50029205370000 1801400 20" N/A 20" N/A 2.5 10/16/2011 WSW -02 50029208120000 1821370 2'10" N/A 2'10" N/A 6 10/16/2011 WSW -03 50029208170000 1821420 12" 1.00 20" 09/11/2011 4.25 10/16/2011 WSW -07 50029208610000 1821880 SF N/A 19" N/A 1 10/17/2011 1C-170 50029231540000 2030780 19'3" 1.20 10" 09/11/2011 18.74 10/15/2011 e 1 1C -174 50029231400000 2030270 7' 1.00 8" 09/11/2011 14.8 10/15/2011 1C-190 50029231360000 2030030 9'4" 1.50 8" 09/11/2011 15.2 10/16/2011 1D-08 50029220266000 1770530 5'2" 1.20 6" 5128/2011 3.8 10/15/2011 10-12 50029229480000 1990840 18" N/A 18" N/A 3.4 10/15/2011 1D-41 50029232880000 2051880 16" N/A 16" N/A 3.55 10/15/2011 10-123 50029229140000 1981700 11'5" 2.30 5" 09/12/2011 4.4 10/15/2011 1E -11 50029207870000 1820510 22" N/A 15" N/A 1.2 10/17/2011 1Y-09 50029209350000 1830520 7' 2.00 5" 09/12/2011 1.7 10/18/2011 Page 1 of 1 Maunder, Thomas E (DOA) From: Gauer, Jenn L [ Jennifer .L.Gauer @conocophillips.com] Sent: Thursday, May 05, 2011 12:44 PM To: Gauer, Jenn L; Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist; Gangl, Melissa A; CPF1 Prod Engr Subject: LLP /SSV Returned to Service on on 1C-174 : 05- May -2011 Tom / Jim, The low pressure pilot (LPP) on tri- lateral injector 1C -174 (PTD 203 -027) was returned to service on 5/5/2011 after the wellhead injection pressure stabilized above the setting of the low pressure pilot. Current wellhead pressure is 605 psig; injection rate is 750 bwpd. This pilot had been defeated on 5/2/2011 in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Jenn Gauer Work - 907.265.6782 Mobile - 303.248.6641 > MAY 06 WI From: Gauer, Jenn L Sent: Monday, May 02, 2011 4:29 PM To: 'jim.regg @alaska.gov'; 'Maunder, Thomas E (DOA)' Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Gauer, Jenn L; NSK West Sak Prod Engr; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt; NSK Prod Engr Specialist; Gangl, Melissa A Subject: LLP /SSV defeated on 1C -174: 02- May -2011 Tom / Jim, The low pressure pilot (LPP) on injector 1C -174 (PTD 203 -027) was defeated on 5/2/2011 when the well was returned to injection service after being shut since 10/28/10. Current wellhead pressure (as of 4:29 PM 05/02/11) is 499 psi at an injection rate of 735 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. ConocoPhillips Alaska, Inc. West Sak Production Engineer Work - 907.265.6782 Mobile - 303.248.6641 5/5/2011 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 January 8, 2011 RECEIVE JAN 11 2011 Commissioner Dan Seamount a Alaska Oil and Gas Conservation Commission ka Oil 4 Gp Cons, C(TPrimission 333 West 7 Avenue, Suite 100 t4ncn! rag$ Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., well 1C -174, PTD 203 -027, Sundry 310 -345 surface casing repair. Please call MJ Loveland or Perry Klein at 659 -7043 if you have any questions. Sincerely, d7,_"7/ ./ 7 MJ Loveland MOW JAN 1 c t ConocoPhillips Well Integrity Projects Supervisor KA ALASKA AND GAS STATE CONSERVA ALAS TION COMMISSI. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ❑ Repair w ell ❑ Rug Perforations ❑ Stimulate ❑ Other pi SC inspection & Pull Tubing I New Pool Waiver repair Alter Casing ❑ g ❑ ❑ ❑ Time Extension [] Change Approved FPogram [] Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. - Development 3 Exploratory ❑ ® 203 - 027 3. Address: 6. API Number: Stratigraphic ❑ Service p P. 0. Box 100360, Anchorage, Alaska 99510 i 50 - 029 - 23140 - - Op 7. Property Designation: c 8. Well Name and Number: ADL0025649 / ADL0025638 , 1C 9. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool e 10. Present Well Condition Summary: Total Depth measured 12485 feet Plugs (measured) 10735 / 10909 true vertical 3876 feet Junk (measured) None Effective Depth measured 12483 feet Packer (measured) 7046 true vertical 3998 feet (true vertucal) 3709 Casing Length Size MD ND Burst Collapse CONDUCTOR 110 16 110 110 SURFACE 7140 9.625 7169 3726 LINER 5476 8.43 12485 3899 SLEEVE 5 12 5 5 RECEIVErt Perforation depth: Measured depth: Slotted Liner 10735 - 12399' True Vertical Depth: Slotted liner 3747 -3865' JAN 1 1 2011 1 Get Corps. Coruission Tubing (size, grade, MD, and ND) 4.5, L - 80, 7045 MD, 3709 TVD • 4.f1t iunge Packers & SSSV (type, MD, and ND) SEAL ASSY - BAKER GBH -22 SEAL ASSEMBLY 0 7046 i D and 3709 ND 11. Stimulation or cement squeeze summary: Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory [❑ Development ❑ Service pj - 15. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Daily Report of Well Operations X GSTOR ❑ WAG ❑ . GASINJ ❑ WINJ W -- SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt 310 -345 Contact MJ Loveland / Perry Klein Printed Name MJ Loy nd Title Well Integirty Project Supervisor Signature / /, �/J one: 659 -7043 Date 1/8/11 RBDMS JAN 111 / /" rc Form 10-404 Revised 7/2009 ,, % ,fzh, (. Submit Original Only 1C-174 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/18 /10IRemove 62" of conductor to inspect surface casing. 12/19 /10IInspector found damage to surface casing that reqiures repair. 01/01/11 1WeId 46" sleeve from 12 "X65.787 wall pipe, over all sleeve is 5'. 01/04/11 Perform MITIA to 2900psi, Start: si (0)/2900. 15 min si(0)/2875. 30 min si(0)/2875. bleed IA to 0. Final: si(0) /0. Insulators denso wrapped. 01 /081111Install 7' of 16" 62.5 .375 conductor. f tea° - 7 R ' . ?+t�•- _ , = i r f c h e i t. $ off` t d rt i 7t a M • ' ' ' 1 '''4*.-1:0:19P ' 1 ' 4 *' - t C t ti - .. .. j `. y ' i , n^' y \ b / Y 1 i .••• . ..,:: .. ,. . .. .. ..„ •• ••:-...•,.. . ,, • . ... , .. ..„•: • ....•• : w ,....a 1 il} .,,...:: .:., . . . . . till 1X. „ . . . 1 . �. ..� • , • . . . . . . • .. . _'- G , _ ,• ... ... .,...,,, . • t a tel a a ter `r • ti ,... .--;,..,-...,,+`..-• _ a 4 > 'S S te ; _ '$ .k'n=1„• !} 1 it` . , • ._ ,,,slo i a...0, .. ', �'-+Ya f,p, r' .. . , i�. ,,d ism - 'ila � F . ; -� may. - , t 'r; _ . ` * fit £: rs� ( f f $ !' X O d , k s � ,;r ' f /{ .1'.......,'./ y - kt' r ^. , 4 „ I i*'e: ti, • ., 9 17 ft _ > s 4 � • ,. :' ,1 q. t1 ” _ —•"'"`"`` '•: 4` . - n ^fi ,� c,. .1 -: [ -? . Page 1 of 1 • Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@conocophillips.com] Sent: Sunday, June 27, 2010 2:29 PM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr 8~ Optimization Supv; Seitz, Brian; Pierson, Chris R; Gangl, Melissa A Subject: LPP/SSV Returned to Service on 1C-174 - 27-Jun-2010 Tom /Jim, The low pressure pilot (LPP) on injector 1C-174 (PTD 203-027) was returned to service on 06/27/2010 after the wellhead injection pressure stabilized above the setting of the low pressure pilot. Current wellhead pressure is 536 prig; injection rate is 550 bwpd. This pilot had been defeated on 06/24/10 in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. David Lloyd Lagerlef/Daniel Bearden CPF1 Production Engineers n1269@conocophillips.com 659-7493 ,;~ ~ ~ ~~ . , ~' `~ 'F ± r; pager 659-7000 765 ~~~''' f 2 ~ ' ly'' From: CPFl Prod Engr Sent: Thursday, June 24, 2010 5:34 PM To: CPFl Prod Engr; "Maunder, Thomas E'; "Regg, James B' Cc: CPFS DS Lead Techs; CPFi Ops Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitr, Brian; Pierson, Chris R Subject: LPP/SSV defeated on iC-174 - 24-Jun-2010 Tom /Jim, The low pressure pilot (LPP) on injector 1C-174 (203-027) was defeated on 6/24/2010 when the well was returned to injection service after being shut in for 112 days. The well was shut-in 3104/10 pending a choke repair and installation of a power wedge. Current wellhead pressure (as of 17:33 6/24/10) is 452 psig; injection rate is 541 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. David Lloyd Lagerlef/Daniel Bearden CPF1 Production Engineers n1269@conocophillips.com 659-7493 pager 659-7000 765 6/30/2010 Page 1 of 1 • ~ • Maunder, Th©mas E (DOA) From: NBK Problem Weil Supv [n1617@»nocophillips.com] Seat: Sunday, June 13, 2010 7:02 PM To: Brooks, Phoebe t (DOA); Regg, James B (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Cc: Schwartz, Guy L (DOA) Subject: RE: May MIT's 1J-176 & 1C-174 Attachments: KRU 1 J-176 06-04-10.xis; KRU 1 J-176 05-22-10.x1s; KRU 1 C-174 05-22-10.x1s Phoebe, Attached are the MIT forms for 1 J-176 that were performed on both 05-22 and 06-04-10 retest. Also attached is the test form for 1 C-174 that was performed on 05-22-10. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 From: Brooks., Phoebe L (DOA) {mailto:pt~oebe.brooks@aiaska.gov] Sent: Friday, June 11, 2010 9:05 AM To: VSK Problem illlell Supv Cc: Regg, James B DOA) Subj~t: May Mils 1J-176 & iG-174 < < t { ~ ~~(-I &~ent~Marti`nR It does not appear we received` the MtT report for 1.f-1..76 PTd X2070990 dated 5/22/10; we also do not have the MlTreports for 1C-174 PTD #'20'30270 dated 5/21/10 (FJ and. 5/22/10 (P). Please submit these reports. If you have any questions please fet me know. Thank you, Phoebe Pi~oebe Brooks Statistical Technician II Alaska Oil and Gas Conservat.ior~ ~a~mmission Phone: 9Q7-79-1±.242 Fax: 907-276-7542. 7/4/2010 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; phoebe.brooks~alaska.gov; tom.maunder~alaska.gov; door.aogcc.prudhae.bay~alaska.gov OPERATOR: ConocoPhillips Alaska Inc" FIELD / UNIT t PAD: Kuparuk /KRU / 1C DATE: 0522/10 OPERATOR REP: Colee /Phillips - AES AOGCC REP: John Crisp Packer Pretest Initial 15 Min. 30 Min. Well 1 C-174 T In'. W TVD 3,705 Tubi 225 250 250 250 Interval 4 P.T.D. 2030270 T test P Test 1500 200 1,700 1,630 1,600 P/F P Notes: OA Well T In'. TVD Tu ' Interval P.T.D. T test Test P!F Notes: OA Well T In'. TVD Tubi Interval P.T.D. T test Test Cali P!F Notes: OA Well T In'. TVD Tu ' Interval P.T.D. T test Test F!F Notes: OA Well T In". TVD T Interval P.T.Q. T test Test psi Corsi P!F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Interval Radioactive Tracer Survey A =Temperature Anomaly Survey D = DiYferential Ternperature Test ~, ~ (~\ INTERVAL Codes 1=Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O = Otfier (describe in notes) MIT Report Form BFL 11 /27!07 KRU 1 C-174 05-22-10 (2).xls MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 25, 2010 TO: Jim Regg ~~~~+iG P.I. Supervisor ~l. SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 C-174 FROM: John Crisp xuPARtnc RIV a wsAx Ic-t7a Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~- Comm Well Name: KUPARUK RIV U WSAK 1C-174 API Well Number: s0-029-23140-00-00 Inspector Name: John Crisp Insp Num: mitJCr100523105834 Permit Number: 203-027-0 Inspection Date: 5/22/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Weld ~ tc-I7a Type Inj. ~ N TVD ~ 3709 '~ ~ Lei 20o t7oo '~ 1630 _t6oo ~ I P.T.D zo3oi~o ' ---J---1 TypeTest SPT II -- ~ _J Test pst tsoo pA ~~ Interval 4~TST p/F P / Tubing z2s 2so zso zso Notes: 4.8 bbl's pumped to reach test pressure. Well was shut in. There was an orifice meter that had absorbant & oily waste bag wrapped around it. This meter was not leaking with well shut in. Should be inspected & problem addressed if this leaks while on mJection. Hopefully the absorb & oily waste bag were not on the meter to slow leak. Tuesday, May 25, 2010 Page 1 of 1 Page 1 of 1 Regg, James B (DOAj From: Regg, James B (DOA) 61~~~a K~ lc-t~4 Sent: Friday, June 25, 2010 2:17 PM ~~(~( ~ ~~_~27 To: NSK Well Integrity Proj; NSK Problem Well Supv Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA) Subject: ANSI 1500 Flanges Inspectors have been finding ANSI 1500 flanges installed on the IA of some wells when out to witness MITs. The rated working pressure for these flanges is 3700psi. If I understand the situation correctly, the ANSI 1500 flange is installed on the IA and would either be directly exposed to test pressure approaching the rated working pressure, or could be exposed to excessive injection pressures in the case of TxIA communication (e.g., high injection pressures on gas injectors or via thermal expansion). During witnessed MITs in late May 2010, ANSI 1500 fllanges were found on West Sak gas injectors KRU 1C-25 and 1C-27. In both occurances, CPAI was advised these are deficiencies. API defines the rated working pressure of equipment to be the maximum internal pressure that the equipment is designed to contain or control, and further notes that rated working pressure should not be confused with testing presssure (I read that to say it is inappropriate to justify operating equipment at pressure exceeding rated work pressure just because it was tested to the higher pressure). Exceeding the rated working pressure represents an inappropriate risk to field personnel attending to the wells. Inspectors have not been able to field verify if ANSI 1500 flanges have been hydrotested to proposed higher test pressure, and even if the flange was tested, we question how you would account for the history (exposure to extreme temps, harsh chemicals, corrosive fluids, etc.). We are interested in understanding CPAI's safe operating practices regarding ANSI 1500 flanges. We are also interested in reviewing any CPAI test policy that allows for the pressure rating of equipment to be exceeded. Other deficiencies noted during the KRU 1C-pad inspections in late May: - Two instances of tree flange adapters made up to tubing spool without full engagement of the nuts on the studs (1 C-10, 1 C-15) - KRU 1 C-119 and 1 C-121 were noted to have mandrel hangers off seat from conductor casing; WAG injection lines were hanging from tree without support, placing the casings in a sideways bind. - KRU 1 C-174 was observed to have orifice meter wrapped in absorbant and an oily waste bag; use and condition of the orifice meter here needs to be explained. Please address these items. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 6/25/2010 MEMORANDUM • To: Jim Regg • ~~~ ~(za ~h P.I. Supervisor r FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, June 11, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 C-174 KUPARUK RIV U WSAK 1C-174 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~I~ Comm Well Name: KUPARUK RIV U WSAK 1C-174 Insp Num: mitJCr100524060011 Rel Insp Num: API Well Number: 50-029-23140-00-00 Inspector Name: John Crisp Permit Number: 203-027-0 Inspection Date: 5/21/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well~- ]ca 7a Type Inj. N ~ TVD 370 /9 IA ~~ _~ 12030270 SPT ~ TypeTest~ P.T.Di ; Test psi 1500 '~~ OA ' ~ ~ ___ _ _ Interval aYRTST _ _ p~F ______ F ~ Tubing ~ 22s ~._ NOtes: ]0 bbls pumped with no_pressure increase. Asked to have annulus filled & tested the next day. Tested the next day (mitJCR100523105834). v Monobore injector. Friday, June 11, 2010 Page 1 of 1 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 1C-174 Run Date: 4/24/2010 Apri130, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1 C-174 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-23140-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNIl~TG A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. U~ ~ Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-335 . ,~e, , , _ rafael.barre~o ` ` 11~ttx~on.'e'ozn ~ , `'' Date: °~ 203 "02~- 1 ~4~v Signed: • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations Q~ Stimulate ^ Other ~ Alter Casing ^ Pull Tubing ^ Pertorate New Pooi ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnoCOPhillips Alaska, InC. Development ^ Exploratory ^ 203-027 /' 3. Address: Stratigraphic ^ Service Q' 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23140-00 • 7. KB Elevation (ft): 9. Well Name and Number: RKB 87' ' 1 C-174 . 8. Property Designation: 10. Field/Pool(s): ADL 25649; 25638 ~ Kuparuk River Field / West Sak Oil Pool ~ 11. Present Well Condition Summary: (1~'.~ ~ ~~ ~JJ r,~c~.s9f~~l~iw6~+~ .~UL ~.~ ~ Total Depth measured 12485' • feet true vertical 3899' , feet Plugs (measured) 10735' Effective Depth measured 12483' feet Junk (measured) true vertical 3898' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SURFACE 7087' 9-5/8" 7169' 3724' LINER 5411' S-1/2" 12485' 3899' ~~~G~ ~/ CL~ Perforation depth: Measured depth: alternating slotted liner from 7021'-12485' true vertical depth: 3706'-3899' ~~~ ~ p~~~~ ~las~Ca pil & Gas Cons. Commission Tubing (size, grade, and measured depth) 4.5", L-80, 7063' MD. ~ AfiCItOPB~E Packers & SSSV (type & measured depth) Baker ZXP pkr, Baker SBE @ 7021', 7051' Camco DB nipple @ 499' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 10735' 20 bbls Ultra LiteCrete Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation 1101 ' 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~• Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ Q~ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-086 contact John Peirce @ 265-6471 Printed Name John Peirce Title Wells Engineer '~ 'r~ Signature / _ ~ Phone: 265-6471 Date ~p" 0 ~ ,t. e Pre ared b Sharon Alls Dr ke 263-4612 /~ ~ , ~`~~~ Form TO-404 Revised 04/2006 i)G~ ~~ ~~~ ~~~~~~ ~j~ Submit Original Only ~-A!~ `:i~~~~~G~f 1C-174 Well Work Summary DATE SUMMARY 5/3/09 PERFORMED FLUFF & STUF~O DOWN TO LOCKUP @ 11162 CTMD• SWAPPED TUBING OVER TO DIESEL, RTN IN A.M. FOR BRIDGE PLUG. 5/4/09 SET TTS 3.5" OD EXPANDABLE BRIDGE PLUG INSIDE BLANK SECTION OF 5.5" LINER (a~ 10909 CTMD. 2ND RUN PERFORATED 5.5 LINER @ 10819 CTMD TO 10824 CTMD WITH SLB 6 SPF TCP GUNS. RTN IN A.M. FOR CEMENT JOB. 5/5/09 PUMPED 20 BBLS ULTRA LITECRETE CEMENT THROUGH RETAINER SET @ 10735 CTMD, PUT .5 BBLS N , ED TUBING OVER ! TO DIESEL. LEFT SHUTIN. ___..~ KUP ~ 1C-174 ! ~~~'j~~~j~~lp~ ,~ ~ Well A;tribut es _ jMax A ngle 8 MD ~~TD ,~, ., ^ ; ~~M.. ~ Wellbore API/UWI Fieltl Name I Well Stafus Incl (°) I MD ((iKB) I ,Act Btrn (ftKB) _ ~ WESTSAK 500292374000 • ~ ~ INJ l 9533 _ 11.151.38 ~ 12,485.0 - C M H25 (ppm) IDa~e iM Wation ~'~,End Date KB-Grd (k) IRig Ralease Dati - -.. aSS~. NIPPLE U ~' . ~ ~ ~Last WO: ~ 1- ~~ I 33.69 ~. 4122003 _ '.._~.~C9~~?._1Z} x9rz0 g~lg9~yy A~2u . :<aav U5a a ~-A taton , iDepih(ftKB) 'EndData Mnofat lasiModBy ~EndDate __ ...___'._ i asi Tan~ ~ 11 391.0 I~ 10/24/2004 IRev Reason. PERF. CMT SQZ PERFS i Imosbor , 6/9/2009 HANGER. 23-- ::,f~ CONOUCTOR, _ __ 0-110 NIPPLE.499- -- GAS LIFT. P.505 NIPPLE,6,300 SEAL ASSY. __ 7.016 SUftFACE,___ 29-].169 SLOTS. 1,333-12,399 ~~ I CMTRetaner,_ 10.7% ~("`~ APERF._ ~I ~~ V 10.819-10.826 ~.~ CemeniS02, ~ ~0.736 ?LUG. 10,909 - Casing Description String 0... String ID ... Top (ftK6) Set Depih (t... Set Dep[h (ND) ..- ~~String Wt... String ... 'Stnng Top Th~d CONDUCTOR ~6 15.062 . , H-00 I WELDED 0.0 110.0 110.0 62.50 CasingDescription 9 9 I~ Strin 0... Strin ID ... P P` ` 9 String...I StringTopThrd To (kKB) Set De th t... Set Depth ND) ... ~, Strin WI... i F 8 n 5 l ~0.0~ ~ L-80 i BTC-MD s ( Description C sn 9 0... Str n ID ... ~Str 9 9 i... Set De th ND Str P( P P( I... g IString...'~StringTopThrd To ttKB) Set De tlh LWER . 512 4_950 7,009.5 12485.0 3.8762 ~ 15.50 I L-80 I. Hytlri1511 ' Liner Details , _. _. -_- __- - _. _- _ . Top Depth . (ND) I T l l I . Top(kKB) (ftKg) op nc , (°) ~'i Item Descriptio n Comment __ _ _ .__ . ID(in) 7,021.4 3,7056 8254!PACKER BAKERZXPLINERTOPPACKERw/HRPROFILE 6290 7,035.1 3,707.3 82.53 NIPPLE RS NIPPLE ~ ~ ~ s~~88 7,037.4 3,707J 82.52 HANGER BAKER FLEX LOCK HYD LWER HANGER ~ ~ 6.310 7,04Z6, 3,709 0 82.51 XO BUSHING CROSSOVER BUSHING 7"xS.S' ~~ ~ ~~ 4.890 i I 7,050J 3,709 41 8Z51 SBE I BAKER SEAL BORE EXTENSION 4J50~ '~Tubing Strings ~.Tubing~ String 0... i5tring ID ... Top (NKB) Set Depth (t... Set Depth (ND) ... String Wt... String ... Siring Top Thrd TUBING . 412 3.950 228 7,063.0 3,711.3 1260 I L-80 i NSCT Completion De ~'.TOPDaP~h tails _ ' , _ . .___ _-_. - _ ~. (ND) ~ Top Incl , ''~ Top (i1K8)'~. (ftK8) (°) Item Description Comme~rt ID (in) 22.8 22.8 -0.82 HANGER VETCO GRAY TUBING HANGER 4500 498.6 497.3~ 7.56 NIPPLE CAMCO DB NIPPLE w/NO GO PROFlLE 3.812 6,299J~ 3,544.1 , 6829 ~ NIPPLE ,CAMCO DB NIPPLE w/N0 GO PROFILE 3J50 7,644_9 3.708.6 82.51 LOCAIOR BAKERG-22LOCATOR 3.875 7,045.6 3,708/~ ~, A2.51~iStALASSY BAKERGBH-22SEALASSEMBLY 3.870 Other In Hole ( Wireline retrievable plugs, valves, pumps, fish, etc.) ..... ..-~ - ToPDepthl ' (TUD) i Top Incl ~ Top (ftK8) (ftKg) ~ (°) Description Comment Run Date ID (in~_ 10J35 .3,831 0'. 93A2~CM1 Retainer '~CEMENT RETAINER 5I5l2009 0.000 10,909 1.82t5 Perforations 8 9342 PWG I3S'TTSIBP .. 5/4l2009 Slots 4.580 __. _ _ -_.__ Shot ~ Top (TVD) Blm (TVD) I DanS Top (ftKB) B4n (flK8) ~~ (HKe) (itKB) Zone Date (sh~~~ Type CommeM 7,333 12,399 3,747.6 3,864J WS D WS C, 3/30/2003 99.0 SLOTS AMemaling 130' Solltl/43' Slottetl WSB 1C-174 I ~ UNDULATINGLINER; A2"z1.5" ~ slots - 10,819 10,824 I , 3,826.1 3,825.9 WS C, 1 C-174 _. 5142009 6.0 APERF - SQZ'd Sf512009 - PUMPED 20 BBLS ' ULTRA LITECRETE CEMENT THROUGH RETAINER w/16 bbls BEHIND PIPE Notes: General $ Safet Entl Date j Annotation 6/9/2009 'iNOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 I Mandrel Detail ......... . . ..- _ ,_ . . .,,... s . . . . . _.._._. ... . ... .. . PoA . .._. .- Top Dept~ Top I V~ Incl OD I Valva Latch Siza TRO Run ~ ~ SN To ftKe (hKe~ (`) Maka I Mod I (~~) Sarv Type Type (~~) (psi) Run Date Com... PI 1 1 2,504.5 1,920.5 fi4.68 CAMCOiKBG-2 1;GASLIFT ,DMY BK-5 0.000 00 S/10/2003 , LINER. • ~ ~ -._~ 7.009-11.685 \ TD,'1P,485 LPP/SSV no longer defeated on 1C-174(PTD 203-027) Maunder, Thomas E (DOA) From: NSK DHD Tech [n1656@conocophillips.com] Sent: Monday, May 25, 2009 11:04 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF2 Prod Engrs Subject: LPP/SSV no longer defeated on 1 C-174(PTD 203-027) Tom /Jim, The low pressure pilot (LPP) on 1C-174 (PTD 203-027) was returned to service on May 22, 2009. Current wellhead pressure is 675 psi, injection rate is 1350 bwpd. Thank you for your assistance, if you have any questions please contact me. Kenneth Lloyd Kenneth Lloyd Martin/David Lloyd Lagerlef Prod. Eng. Regional Advisor/Staff Engineer CPF1 Production Engineers Kuparuk River Unit Phone: (907) 659-7493 From: CPFl Prod Engr Sent: Wednesday, May 13, 2009 10:48 AM To: "Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)' Subject: LPP/SSV defeated on iC-174 - 13-MAY-09 Tom /Jim, r " ~U~~-' ~.', krs ~ .rn+~ Page 1 of 1 The low pressure pilot (LPP) on 1C-174 (PTD 203-027) was defeated 5/13/2009 when the well was returned to service after being shut in since 2/27/09. Current wellhead pressure is 65 psi, injection rate is 500 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001". David Lloyd Lagerlef/Kenneth Lloyd Martin CPF1 Production Engineers n1269@conocophillips.com 659-7493 pager 659-7000 765 5/25/2009 • • ~ ~ ~ _ t f ~ ~pr~~-~~ a ~ ~: .--~,~~, s ~ ~~'~~`~ ~ ~ ~ ~ ~ ~1 N ~ ~ f .~~ ~ ~~' ~ ~ ~ ~ ~ ~ ~: ~ ~~ ~ ~' k ~ e k~, ~~. i ~ ~ - r I~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ -~ ~ E ~ ~ ~ ~ ~q ~ ~ ~ ~ ~~ SARAH PALIN, GOVERNOR ~ . I ~ ~ 1? ~.~ ~_w~ ~~ ~~ . ~!~ ~ ~. ~~ :1 ~ ~ ~e. ~. .._~ ~,_~ ~AS$A Du~ t~1`D ~s ~ 333 W. 7thAVENUE, SUITE 100 CO1~T5~RQA'1`IO1~T COMrIISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 _. .. -FAX (907) 276-7542 Guy Schwartz Wells Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage AK 99510 ~y 5 ' ~ ~ ~ ' ~ ~f v ~ , ;,~'+u~:-.~ . .~1 ~w: C, wv 1.. a~3~ ~~. Re: Kuparuk River Field, West Sak Oil Pool, 1 C-174 ~ Sundry Number: 309-086 Dear Mr. Schwartz: Enclosed is the approved Application for Sundiy Approval relating to the ab~ ~ e referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~day of March, 2009 ~ Encl. ~inrPrPlv ~ q ~~~ ~ STATE OF ALASKA ~ " ~ ~?~~~:~~~~'~P~ O \ ~3 ~ ~3ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ ~PPLICATION FOR SUNDRY APPROVAL ~~~ "~ ~ ~~~~ ~ 20 AAC 25.280 ~.,e__e._ ;~:s r~. e^~.... ~.,.... C'e~oeimiccintR 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ~I~i~~r0~a~~ Other ~ Alter casing ~ Repair well ^ Plug Perforations ^~ ' Stimulate ^ Time Extension ~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConoCOPhillips Alaska, Inc, ~evelopment ^ Exploratory ^ 203-027- 3. Address: Stratigraphic ~ Service ~/ ~ 6, API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23140-00~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership ch anges: Spacing Exception Requires? Y2S ^ NO ^~ 1C-174 • 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25649, 25638 ~ RKg g~~ . Kuparuk River Field / West Sak Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective ~epth nn~ (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 12485' - 3899' - 12483' - 3898' ~ Casing Length Size MD ND Burst Collapse COND~JCTOR 110' 16" 110' 110' SUR~ACE 7087' 9-5/8" 7174' 3726' LI N ER 5411' S-1 /2" 12485' 3899' Pertoration Depth MD (ft): PerForation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slternating slotted / solid liner from 7021'-12485~ 4-1 /2~~ ~-$~ 7062' Packers and SSSV Type: Packers and SSSV MD (ft) Baker ZXP pkr, Baker seal bore extention @ 7021', 7051' Camco 'DB' nipple @ 499' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^ Service ^~ 15. Estimated Date for 16. Well Status after proposed work: ~ Commencing Operat March 17, 2009 Oil ^ Gas ^ ' Abandoned ^ Plugg ~ 17. Verbal Approval: Date: WAG ~ GINJ ^ ,/ ,- WINJ l~d WDSPL ~ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Guy Schwartz @ 265-6958 Printed Name GU W8 Title: Wells Engineer Signature ~ Phone 265-6958 Date -z' ~ dc~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~~ a~ ~~,~.~~Y~c~ s sti Plug Integrity ~ BOP Test [~ Mechanical Integrity Test ~ Location Clearance ^ ~ C.-O'~ ~ Other. 3SO V ~US i ~-``~d~ iv-~v v-~~ \ ~~ ~JD ~ ~S~ ~ ~~4~5\ d~\/~ l ~'~'`LQv~v~~j~CsC _. C Subsequent Form Required: ~ APPROVED BY ~~ / ~~ Approved by: C ISSIONER THE COMMISSION Date: Form 10-403 Revised 06l~(~06~~ ~,--, j/ y..~ Submit in Duplicate ~ 1, ' ~ r ~e ~ ! ~~ ~ ~~. M~ii li ~`, ?~Q9 ~ ~ ~ . • • Sundry Request for 1C-174 MBE Remediation 3-1-09 Background: West Sak 1 C-174 was drilled as a horizontal undulating injector (HUI) lateral in 2003 (the wellbore undulates between West Sak B and D sands). A MBE event to producer 1 C-178 occurred 3-8-2007. Diagnostics have identified the MBE breakthrough in the area deeper than 11000'md in the HUI lateral. This puts the MBE in the area of D sand pay. This is in the lower 1/3 of the horizontal wellbore and correlates with the D sand response in the offset producer 1 C-178. The most economical method to fix the injector and allow injection again is to abandon the lower 1500' of the wellbore with cement (from 11000- 12485'). Standard Class G cement will be pumped followed by a cap of blended Thixotropic cement to prevent migration of the cement in the horizontal wellbore. 1 C-174 has very small slots in the liner (.020" x 1.5") so will perforate in the area of the MBE before pumping cement. A newly developed Coil tubing deployed swab cup tool will also be used to help place the cement in the liner x OH annulus and minimize migration of the cement during placement operations. Procedure outline: 1. RIH with 2" Hybrid Coil Tubing. Perforate 5%2" liner at 11500- 11502' md . POOH. 2. PU Swab Cup tool and RIH to 12485' md. Open Swab tool. 3. Pump class G cement while POOH 1-1 from 12485'- 11000' md. ( will use approx 110 bbls - 8.5" OH with 5%2" slotted liner) 4. At 11,000 lay in 5 bbls of Thixotropic cement for a holding cap and POOH. (Hold 50 psi surface pressure if possible while POOH to help hold cement in place) 5. Return well to injection. . ~ ~ :, ~~~1 ConacoPHiltips Aia~k~, inc. KRU 1C-174 ~' i c-na - ~I: SrJG~S^_314t;Q~ Well T~_: 4NJ Se t~v- TS. de fa -~~err SSSV 7ype ?JIPPLE Ony 4f~;~QG3 r',ngie C TD. 8~ deg Cy 1~4:~= a--~e_ o-~ a sco r'~i etion v , . . io.a~, „nnular=lwil-. Lsst4+lrQ RevReason. ShowPERFS . . 5•3L=FCE RB!MBt1CP ~ J~ ~v~ RY:E f~.el '_iiJ ~;ufF~ G931 ~ 918. ~(~~.'~05 ~~?,;<. r~5 y9:s Lsst 7u . 1^;'91' ~~-7PdG TG: t='4,~',S t;iCS - . . w._o.x~, ia~ T8Q Cete 1 J~~4;_GPS 1:'..s:.: H~~IS '•n~ IE' 3~ de, ~;_. 111~ 1 ; ° ' Casin Stnng - UNDULATING L INER (Altemat in 130' Solid Lin er w/44' Slotted Liner SecLon~, ~ ~s_ ~ ~~azvo~.m~-Y :{. I , _ Descs+ ia~ Size To Bottom TVD Wt Grode 7hrP,y ~ ' oa c . + UP1ER ,~r~ ~'4 1~4c~ t_°4cy 15.~0 L-80 Hvdr ~::a ~ s ~x~sa~ - ' - SLOTTEGLIh2~~ F.opCl ;33s 1~3~ 386~ 15.50 L~3G H r_-. _. . ~ Casin Stri - ALL STR INGS ~ Descri tian Size To Boltom TVD Wt Grede Thtead ~ ~OF.FF:^E 9.E°5 Q 7l'4 3:~6 3QG0 L-8~ BTi:-tvSU CONDUCTOR 16_060 `J 1f0 tt0 6°5~ H-00 WELDED Tubin Strin - TUBING Size To Bottan ND Wt Grede Thread ac~ '15G0 ~~ ?G6: 3it1 TZ5~~ L-8~ NSCT ~saa.e uo ss~, Perforations Summa Intarval TVD Zone Stetus Ft SPF Dcte 7 Cnmmen{ ;333 - 2^399 3P4S 3855 1NS D.WS 5Q66 ~4L` 3~a2th~3 Slotte~d FJternatirg 39` sbtted Piner C,LNS Linar w;43'solidliner B.W& :,~5 t~ ~I D.4b`~5 C.1 JS B.+NS u~rr',IF - . C.~VS i~at=-'x: D.YY~~ oo^.esc~ ~ C.WS B sea~ --• --- Gas Lift Mandrets/Valves ~-"' ] St MD TVD Men Men T YPe V M6 V T YPe V OD Latch PoR TRO Date Viv nr,-_,c ~ Mfr Ru Crr_ni , i ~~C4 19^_ "v CAP.f~C BC-~ QtdY 1.~ BK-5 ~.060 0 Si10l..003 Other lu s e ui . etc . - JEWELRY ~ ," th ND T Descri tion IC , ~H ~-r,a;.;;,s, 23 ~3 HiaNGER 'rETC~ti} GR~Y T6G H.~NGER, h,qr~A T~~F C~3NNE~TOF 4.~~! ~~ ~*.~, ay~ ,3g NIF CA63C[;'p~ N!RPLE'Jl:NOGGPRC~r~LE 3." . - c:i_r~ 35-04 NIF ~,:M1SCO DE P~IFPLE'~h.';NO G~ PFO~iLE ~-_.~ , - . '~44 ~?09 SE4L E~iKEF~i-~'_Li~•,'r"TC?RJEi~tLr~S$E2e~7LY . ~~~E Other lu s e ui . etc .Z LINER JEWEIRY nes,.~~;:~, oo-s:sc ! - De~ ~th TVD T Descri ~on IC ~. ~ :?06 l,n~r BAKER ZXP PACKER ih`lH.~'3 PRO~ILE 6.~9U ~ FACKcR ~;,,~~~~,F _ _ 'Ci~~ 3'07 Lir.ar NIF R; NIPPtE 6.188 i~c-a ~~;a. 7U48 37i15 L~ner X.O CROS50V£R BUS'HltdG 4.890 aos =oc~ 7~51 3i0S Liner SSE Bk~CEF SE'~L HOf:E EXFENSION 4J50 't7; 3_ ~ner ~J L- Hv~ LL 51 ,;C~LIG ~4. 0 7~399 3~5 L~ner A~ER INSERY PAi.KOFF O.D00 PCai KOFF 1^383 .i876 L iner SHQE WEATHERFORti REAh7ER SHO£ 4.950 Uh'cR ~za~~~:was. C€1'5.567. I I _ _ ~ .vr u x; Aerf t73w-~~26'~ ' ~ ~ ~ ~ SLOT'EG~ I ~ LINcR !733& 1.3&J. ~ GG:5.5P7. ~ wt~ssc~ ' , ~ ~ ~ -.:-~ ~ ~ _' _ L~:n:ar S WJE iiaa~i^aen. 0o s am '' ~ ~ Well 1C-174 Inteiperted Mcasured Depth Prof'ile ,~,~,~, . ~ _ ___ _ . _-- _.._. __. . _. _.~ ..... _.. _ _.__... . _._..__ . __ . __ , • _ . ~ ~~ , ~~,~„ ~: ~ ~. _s,~,,~,. ; a ~„~, -~~,~, ~~~ do,~~,~~. ~ ' ._...~r,~i.~,rr~r<<~~w«<S~.~kas,mi ' ~~ i 3?UO . ~ ___...T~~p\VecttiukC ~ ' ... . . S:IM~ - _ . _T:ry`A .lS kH-5 I ~l ~ lr,n FIJ ~. ~ .•^Y.n ~ ol I m~i L 14 c.l 1a1, tt.;'aini ~ ;:FGiI ~ ~ ~I yUpnu.>? ~ -- t ' . ... . - . 4?' ;'r)II ~ ~ q. 1.K W. tiuAl:~ ~ rKi?~ - .~. „_ To~ ~ L' ti W~1 ~R 7 ma l 3i'I' fW ~tC ~ ~ ~ ~. ~ ~ ~ n1 j i~ .-_"".._ IA t~ I P I~i~l. Hnl I ti ~nl ti~iivCy~ ~ . 3 i I P~ulilc "1 I I '~~tt i i tG(10 t ' . .. . ~ ~ '- _..,_ .. . _ . _ _ ..-. . ' ` I 'J 1 ... __ '_' _.... la-s .. ~ ! ~~ ' . y ~_._ __ _ __'~„_._.._ ~ __ + ..._ .. ~.A% ~_ ~.~ . - ~ . _ .... i71H1 3 .__ __.__,__~-_~_ ~4 . .. _-~--•~~- ~ -_ _ _~ .~ ~ ,u ~ -__._ _ ai~ , ~. _ ~ - . ___._._ __ F `' -, ~' _ .._.._~ .__w ` ' ~ a ~ - -a-.-~Ctr ~_ " - ~ ' `~__' _ }Y00 ~~-~p Is-S ~ ~ I! ~ dp~nirent D~p - 1 t0" . ~1~~µv . _... . _ o n 17ip. 0.6a' . ~ ~-_-°•~~-----i - ~ .\~i~inr~iill>i~i~ Ilii' A~iparvul V I~ ~ U.3(i' :~.~~I~.,~ I.i~ ~.~i. ~ . ~ 3900 i Lt:n'~,~ 6~:nMl 1'arsH 7a,~~c ~ . o~ im~n ~op;~r n s,mD I`_' ___----.~J . 4q00 ...._ _ . _. . . .. .__ . _ - . -. __-- __ _. __ . . .... . .... - , .. . ~ ~~ ~ ~ ~ ~ ~ 3 ~ ~ ~ _ ~ . ~ ~ .~ Nlt';~SUn d Dcpfh MBE area in D sand • • ( ~~~~~~~ ~ a a ~ ~ ~ SARAH PALIN, GOVERNOR ~.... ~,. ~A~7"~~ ~~ ,tu`D G~a7 333 W. 7ihAVENUE, SUITE 100 Co~5ERVA~oK Corn-II5S~o~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Guy Schwarkz Wells Engineer ConocoPhillips Alaska Inc. PO Box 100360 I'~ Anchorage AK 99510 3~' ~~~ ~O Re: Kuparuk River Fleld, West Sak Oil Pool, 1C-174 Sundry Number: 309-086 :.=~~ ~~'~~~ JUL .`~~ t~ 20~~ Dear Mr. Schwartz: Enclosed is the approved Application for Sundiy Approvat relating to the ab~ ~ e referenced well. Please note the conditions of approval sei: out in the enclosed form. When providing notice for a representative of the Corrunission to witness any required test, contact the Commission's petroleurii field inspector at (907) 659-360? (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commissi~n grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next wor~ng day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~day of March, 2009 ~ Encl. ~in~PrPlv_ • ~ f~~:~~~~~~~ ~~ ; ~ STATE OF ALASKA !'4`?:'tii ~~ ~~ ZOO9 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FORSUNDRYAPPROVAL`~~~'~'a''~:''~'.'~~~'~~~~~°~ar~~ssi~~ 2a AAC 25.280 °~~~~~~r~~ t, Type of Request: Abandon ~ Suspend ^ Operaiional Shutdown ^ Perforate ^ Waiver [] Other [~ Alter casing ^ Repair weli ^ Plug PerforaUons 0 SUmulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConoCOPhillips Alaska Inc. Development ^ exploratory ^ 203-027 , 3. Address: Strattgraphtc ~ Service ~ 6. API Number: P. O. Box 100360, Anchora e, Alaska 9951 ~ 50-029-23140-00 7. If perforating, closest approach in pooi(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? YeS NO Q 1C-174 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25649, 25638 RKg g~~ Kuparuk River Field ! West Sak Oil Pool 12, PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth ND (ft): EffecBve Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 12485' 3899' 12483' 3898' Casing Length Size MD ND Burst Collapse CONDUCTOR 110' 16" 110' 110' SURFACE 7087~ 9-5/8" 7174' 3726' LINER 5411' 5-1/2" 12485' 3899~ Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slternating slotted J solid liner Kom 7021'-12485~ 4-1 /2~~ ~-8~ 7062' Packers and SSSV Type: Packers and SSSV MD (ft) Baker ZXP pkr, Baker seal bore extention Q 7021', 7051' Camco 'DB' ntppte (a3 499' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^ Service ^~ 15. Estimated Date for 16. Well Status after proposed work: ~ 3t• Commencing Operat March 17, 2009 Oil ^ Gas ^ ~u'~ Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ~ WDSPL ~ Commission Rapresentative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Guy Schwartz @ 265-6958 Printed Name GU W8 Title: Wells Eng(neer Signature ~ µJ-i Phone 265-6958 Date -,"~ ~ d`j COt17117~SS10I1 U5@ ~Ill Sundry Num~ Conditions of approval: Notify Commfssion so that a representative may witness Plug Integrity ~ BOP Test "~ Mechanical Integrity Test ~ Location Clearance ^ ~~ ~~'1v~'C~ ~~`~, C ~~ _t . Other. ~ J~dO~S ~ ~iJ~ti~~ ~ ~. , ~~ ~ '"~-~5~~ ~ 5~~'eS ~ r7~r~i~' Subsequent Form Required: 1..~` APPROVED BY ~ ~D ~ ~ D t Approved by: MMISSIONER a e: THE COMMIS510N r:'~ [ F! ^"/`? ,-~ s- Submlt m uupuca~e Form 10-403 Revised 6 4 0 ~~ / • • Sundry Request for 1C-174 MBE Remediation 3-1-09 Background: West Sak 1C-174 was drilled as a horizontal undulating injector (HUI) lateral in 2003 (the welibore undulates between West Sak B and D sands). A MBE event to producer 1 C-178 occurred 3-8-2007. Diagnostics have identified the MBE breakthrough in the area deeper than 11000'md in the HUI lateral. This puts the MBE in the area of D sand pay. This is in the lower 113 of the horizontal wellbore and correlates with the D sand response in the offset producer 1 C-178. The most economical method to fix the injector and allow injection again is to abandon the lower 1500' of the wellbore with cement (frorn 11000- 12485'). Standard Class G cement will be pumped followed by a cap of blended . Thixotropic cement to prevent migration of the cement in the horizonta( wellbore. 1 C-174 has very small slots in the liner (.020" x 1.5") so will perforate in the area of the MBE before pumping cement. A newly developed Coil tubing deployed swab cup tool will also be used to help place the cement in the liner x OH annulus and minimize migration of the cemenf during placement operations. Procedure outline: 1. RIH with 2" Hybrid Coil Tubing. Perforate 5%Z" liner at 11500- 11502' md . POOH. 2. PU Swab Cup tool and RIH to 12485' md. Open Swab tool. 3. Pump class G cement while POOH 1-1 from 12485'- 11000' md. ( will use approx 110 bbls - 8.5" OH with 5'/" slotted liner) 4. At 11,000 lay in 5 bbls of Thixotropic cement for a holding cap and POOH. (Hold 50 psi surface pressure if possible while POOH to help hold cement in place) 5. Return well to injection. . • „ . KRU 'I C-174 . . ~onacrr~'hitfips Alaskay inc, ~' i c-na AP : 5 292314G00 e~l T ; tNJ te Gv TS d ivea~ g$S1! Type: NIPPLE Orig 4.l2W3 Ang1e TD: 8~ d¢g 12485 ~i0~- eiioe: o-a~.xa ~oarss~ AnnulerFluid: LastWtO: RerAeason: PERFS stxwa,ce peference L: 28' RK8 Ref L Dote: Last ate: 812 005 catirs. LastT : 1239PCTMD TD: 124S5ttK6 ~~ ~j 1. e Date: 1 4 0 Mae Hale le: 85 11751 Casin Strin - UNOULA ING L INE R Aitarnst in 130' Snl d Lin ar wl44' Siotted Liner Sections ~~~ ,,,tr,uw,,,,,y - Descri ion Sixe To Bottom TVD Wt Gmde 7Aread ~«+ ~ t NER 5.500 7074 12465 12485 15.50 L-80 rd 5i t ~ ~j __ S D LINER 6.500 7333 72399 3 15.b0 L-80 r~ 57 t 6y Casin Strin -ALLSTRi NGS Deacn tion Sas To BoHOm TVD W Gteda Threed RFAC 9.625 Q 7174 372 40.06 L-80 BT4MD CONOUCTO 6.000 0 t 110 6:.50 H-40 W'ELDED Tubin Strin -TUBING $iz To Itom TVD Wt Grdde Thrend ' ~' 50Q 0 70 3711 12.60 L-8Q NSCT ooa~eao'j Perforations Summa Interval TVD Zona Stewa Ft SPF Dete e Cornment 7333 - 37~i8 - 3865 D.WS 5066 40 3139(taQ3 5lotted AUemafing 36' slotted Einer I C.W3 Linsr w(43'sofW Gnar ' s.ws ~ ~ c.ws o.ws c.ws e.ws uo..Nw n, C.~A+3 4VS D p sawa ~:*~~ . C.WS B s~,u. _ Gas Lift Man dralsNalves ~=°a _-_ St MO TVD Man ~AmType VtiA1r Type VOD Letch Port TR6 Dete Vlv R t - --•-:~_y ~ ~ M 8 1 .. thar lu s e ui . eta. - J LRY ps TVp T e Desm tio ID ~ ~° 23 3 i HANGEH TCO GRfiY TBG HANGER. MGA TOP CONNEGTOR 4. 7 oar¢xy 499 . d98 NIP CAMCO'DB' NIPPL W t~ GO PRO~IIE 3.812 63p0 IP MCA ' N~ NO GO PROFILE 3.750 -?2 L 3.870 ~~~E Other lu s e ui , etc. - LINER JEWELRY R~~i :~;, " NO T ~asai don ID h 7021 706 Lir~r R AC R' R PR r E 6.?90 ~ ~` PACKER ~~ - .. x~er PPL 6.1 1~0747f173 ~x ~@f ~ • . ar6mo~ ''~}`', 70 1 ~ner38E BO 4.7 ner 0 12399 . PaCKOFF 12 3876 Uner E FATHEftFOROREAMERSHOE 4.950 LNER t70T~-72a95. I ~ ~ OPA5C0. . Wt15.70) De~t . p3..'~3~R3W) ~ ' _''~ ~ 5lAPED I IAER C733312390. ~ W35~. Wt15.50) ~ . ~ 1 ~ ~ ~ x=~ :~7 : ~c.;~ L:nx 6F+OE ' (t:i33-13a84. Oa3600) 3U09 - 3100 - 3?tw i 33 W ~ 3~on ~ ~ i~nu ~ 3fi1N1 `u > Z 3~00 , F ~xoo 3900 4000 . ~ ~ l ~ Well 1C-174 Iiiteiperted Mensured Depth Profile _ ._-. .. . ._'-~_.._.~.....___.~-_~...-.."- ~ -____ -,...- . ..o-Snnvy ' - -'._..~___._.. i U~ ~ i t ~- - -~ r.,..em~~~ Bo~.iwi~ •; i . ' .--'tYM tif7lryet Weai Sak DSmM ; i -^T~piWep~tiakC 4 i :~ ! -Tap WCH Ssk A.avwl : ~,,~ vanu n ~ i..~..nnwon~~n•iw~>~saiaso~~; ~ ,~ 'i'a~us~w:i -----.--_-~----- - ~~ ]'ap~1D.Swxl1~vyv7aaw . . . v~SuGf. ~ K~3 ppfraavy+~~fwa~9okC) ... . ~ , .,~ Ac~iml flnniuiW NatiW fn+mSumY' Nl:uni.il B~veNule PrWilu~ LppP-SNwll. / APlurnnl0i~i-I.7M dpp~icntPtp-0.69" ___ .~- _ M%~M1~ ~/ ~yq~areu~ Aip•• I.f~?" Al~p~nmi Ui~~ -UJf+` Dw 0,~'aa! T+n;a?a~o f20' fn~m iry~ ut 0-R:ud) ~ ...... ..,... .. _.;..,-.._~ - ^-ry-~."-'-._.._--°r---'----.-•--.__. _. ~__- S_. .._. g 3 $ ~ $ 8 25 S g 25 '~ Mc:ISUn:cl pcptit I , 8 ~ . MBE area in D sand FW: LPP/SSV no longer defeated on 1C-174 Page 1 of • Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Tuesday, March 03, 2009 10:27 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Pierson, Chris R; Gangl, Melissa A; Hibler, Kaycee Subject: FW: LPP/SSV no longer defeated on 1 C-174 Tom I Jim< West Sak injection well 1 C-174 (PTD 203-027) was shut in 27-Feb-2009. The wel( is no longer operating with a defeated low pressure pi o . Please iet me know if you have any questions. Eric Hollar / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 ~~L~~jl~~ ~J~ ~~; ~ ~~ i' u ~: From: NSK West Sak Prod Engr Sent: Thursday, February 26, 2009 12:38 PM To: 'Maunder, Thomas E (DOA)'; 'jim.regg@alaska.gov' Cc: CPFl DS Lead Techs; CPFl Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Pierson, Chris R Subject: LPP/SSV defeated on iC-174 Tom /Jim, The low pressure pilot (LPP) on 1 C-174 (PTD 203-027) was defeated 2/26/2009 when the well was returned to service after being shut in for approximately 2.5 months. Current wellhead pressure is 479 psi, injection rate is 926 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001". Eric Hollar / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 3/3/2009 FW: LPP/SSV no longer defe on 1C-174 Page 1 of 1 • Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Saturday, December 06, 2008 5;16 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr Subject: FW: LPP/SSV no longer defeated on 1C-174 Tom /Jim, West Sak injector 1C-174 (PTD 203-027} was shut in on 5-December-2008. The low pressure pilot is no longer defeated. Please let me know if you have any questions. Eric Holler / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 From: NSK West Sak Prod Engr Sent: Saturday, November 22, 2008 10:54 AM To: 'Maunder, Thomas E (DOA)'; 'jim.reggCalalaska.gov' Cc: CPFi DS Lead Techs; CPFi Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr Subject: LPP/5SV defeated on SC-174 Tom /Jim, The low pressure pilot (LPP) on 1C-174 (PTD 203-027) was defeated on 11/22/2008 when the well was returned to service after being shut in for an extended period of time. Current wellhead pressure is 275 psi, injection rate is 735 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001". Please let me know if you have any questions. Eric Holler! Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 12/8/2008 09/15/08 ~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~! Well Job # :~~~. , Log Description N0.4871 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD iC-172A 11978478 PRODUCTION PROFILE ~- 08/19/08 1 1 1C-172A 12080429 GLS/FBHP 08/19/08 1 1 3M-26 12096533 SBHP SURVEY 08/20/08 1 1 3N-02A 11996652 SBHP SURVEY 08/20/08 1 1 3M-22 11966276 SBHP SURVEY - 08/20/08 1 1 3C-17 11996657 SCMT C7f5 - /(n ~} /L/ 08/25/08 1 1 3C-15A 11996659 PERF/SBHP SURVEY .a0~-p~~ ~toG~l~ 08/27/08 1 1 2U-06 12080428 LDL _D - 08/29/08 1 1 2V-15 11996661 PRODUCTION PROFILE d --p 08/29/08 1 1 2T-19 11996663 PRODUCTION PROFILE 08/31/08 1 1 2D-07 11975790 INJECTION PROFILE - jt-l ~ Q 09/07/08 1 1 2H-09 11975788 PRODUCTION PROFILE ~ 09/05/08 1 1 iC-174 12096539 INJECTION PROFILE - ~ p 09/07/08 1 1 2H-12 12096540 PRODUCTION PROFILE ~ ~ 09/09/08 1 1 30-01 11975792 LDL `y-U~ 09/09/08 1 1 3F-10 11975789 LDL ~ 09/06/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • LPP/SSV returned to service o:C-174 ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Hunt, Hai L [Hai.L.Wunt@conocophillips.com} Sent: Wednesday, September 10, 2008 8:12 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr Subject: LPP/SSV returned to service on 1C-174 Tom /Jim, 1 C-174 (PTD 203-027) was shut in 9/9/2008 after an injection profile was completed. The LPP/SSV function has been returned to normal. Please let me know if you have any questions. Regards, Hai Hunt '~ ~~~ ~~~ ~ #~ 2~~$ From: NSK West Sak Prod Engr Sent: Thursday, September 04, 2008 5:15 PM To: 'Maunder, Thomas E (DOA)'; yim.reggC~alaska,gov' .. Cc: CPFl DS Lead Techs; CPFl Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr Subject: LPP/SSV defeated on iC-174 Tom /Jim, The low pressure pilot (LPP) on 1 C-174 (PTD 203-027) was defeated on 9/4!2008 when the well was returned to service after being shut in for an extended period of time. The well was brought online for an injection profile that is scheduled to occur on 9/6/2008; the well will be shut in again after the job. Current wellhead pressure is 2 psig; injection rate is 919 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001". Please let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhitlips Alaska, inc. Phone; (907) 659-7061 9/10/2008 • `~_~ --,. ~~`" -~`~ . MICRQFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THiS PAGE F:\LaserFiche\C~rPgs_Inserts\Microfilm_Marker.doc . . ~ ConocoPhillips Alaska RECEIVED JUL 1 0 2007 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Alaska Oil & Gas Cons. Commission Anchorage July 6,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~"J.- o~7 &tA:J 5r1~"tNr;o JUL 1 1 2007 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water ffom entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of fonn 10-404, Report of Sundry Operations. Please M.J. Loveland at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 1 C-125 201-199 11" na na 4.8 6/912007 1 C-170 203-078 23" na na 14.5 6/912007 1C-174 203-027 28" na na 9 6/912007 1C-178 203-041 40" na na 16 6/912007 1C-184 203-089 24" na na 10.4 61912007 Kuparuk Field June 9,2007 . . E\\lEJ) F~e.C .. \JI~R 1 3 'l5JIJ I G ~Ph·ll· . Gas r.ous. onoco I IpS *,\8, Q\\ & þ."c\\O(aq¡~ Robert Buchholz / Robert Christensen Production Engineering Tech. Greater Kuparuk Unit, NSK-69 PO Box 196105 llnchorage,AJ( 99519-6105 Phone: (907) 659-7535 Fax: 659-7314 March 9, 2007 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commissio~c;ANNED MAR 2 0 Z007 33 W. 7th Ave. Ste. 100 Anchorage,AJC 99501 Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has completed the West Sak EOR Pilot Project. Enclosed you will find 10-404 Report of Sundry Well Operation for ConocoPhillips Alaska, Inc. weIll C-17 4 (PTD ~27). The report records the change of well status from WAG Injection to Water In~tlOn Service. -? þ.Þ '3 .w' 0 ( If you have any questions regarding this matter, please contact myself or Robert Buchhloz at 659-7535. Sincerely, Robert D. Christensen Attachments k I:: C; f:: IVE D MAR 1 3 2007 Alaska Oil & Gas Cons C '. REPORT OF SUNDRY WELL OPERATIONS Anchora . OfTImíss,o¡ o ~GlN to WlNJ Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . " 1. Operations Performed: Abandon D Alter Casing D Repair Well D Pull Tubing D Operat. ShutdownD Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchora e, Alaska 99510 7. KB Elevation (ft): RKB 87' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: ,liD.. % ~'" '3 z. )'41 Total Depth measured 12485' Plug Perforations D Perforate New Pool D Stimulate D Waiver D Other Perforate D 4. Current Well Status: Development D Stratigraphic D Exploratory D o 203-027 1 6. API Number: 50-029-23140-00 Service 9. Well Name and Number: 1C-174 "~.'4. .07 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool / feet true vertical , ~'~1'f feet fÞ¡.I('· ~et Plugs (measured) Junk (measured) Effective Depth measured true vertical Casing Structural CONDUCTOR SURFACE LINER SLOTTED LINER Length Size 110' 7087' 5411' 5066' 16" 9-5/8" 5-1/2" 5-1/2" Perforation depth: Measured depth: 7333 true vertical depth: 3748 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7062' MD. feet MD TVD Burst Collapse 11 0' 110' 7174' 3726' 12485' 3876' 12399' 3865' ~ ~J:\c.:, \"~",-2ro,, <>-~\'\">-iJ ~~ ~\C) d-~.aÖ\ \ Lvs-\-V\~\~JfC:.~~~ \~ \0 .-+~ ~ ~\ \ 51cxo.. P~~L-\ ~\Jt)~ ~~..:y,\'£>O~\ t\,~A-\.<:>~~~'1"":i~C-~~ ~'{ ~ì. ~() g;/~\ ..?~. ~ \ \ sk~ c.\-n~ b \ ~\~ ~ <t. ~~ ~ C; 1\ -Oc., h-t?')/l"'> ,,~-o "> Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 499' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 436 25 453 Subsequent to operation 436 25 453 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development D Service 0 Daily Report of Well Operations _ 16. Well Status after proposed work: OilD GasD WAGD GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: N/A Contact Printed Name Signature Form 10-404 Revised 04/2004 \.F)\NA,L Title Phone 659-7535 Production Engineering Technician Date .3 O¡ e::¡- l" MAR 1 9 2007 ~ 1·1¿"07 SU~i?þ?~~ . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 1 00 Anchorage, Alaska 99501 (907) 659-5102 SC!~NNED ,¡ ( .L ~' RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8952 1) 2) 3) 4) 5) 6) 7) 1 Report 1 Report 1C - 174 10-119 MTT Log MTT Log 12-oec-G6 U...:cC ¿J03 - 08'7 13-oec-G6 u.:r. Q. /0"7-- d (1 d Print Name: (2 ill /11 ' 1::. t·/);] r1;')T ì ¡"I ç; Signed: Date : ¡}({J £1/11 k P-(",-- "":',1,:\;;_{:) I;'}": c":; .,~,-~:" - ~<,-:, .".... ,~- "" PRoACTIVE DIAGNOSTIC SERVICES, INC., 130 w. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: ?:::s;--\}j(~:+:--;;Z;~3;:=\j);\12;',j~0::t~.":".:>3<G;')N¡ WEBSITE : /j'jij~fJ,.';¡C:;V¡G,'ž'.·'-CG"::C:;iÌ D\OO _ PDSA,'C-2006\Z _ W ord\Dístnbution\Transmittal_ Sheets\Transmit_ Original.doc I I I I Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: Pipe2 Desc.: Pipe2 Use: Pipe3 Desc.: Pipe3 Use: I I Inspection Type: Assess External Corrosive Damage (Metal Loss) to Surface Casing. This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total metal thickness of the 4.5" tubing, 9.625" surface casings, and 16" conductor pipe within the logged interval. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (180'), where the readings are assumed to represent undamaged tubing, casing and conductor pipe. All other readings are relative to this reference point, which include influences from the 4.5" tubing, 9.625" casing, and 16" conductor pipe. I COMMENTS: I I I . . Memory Magnetic Thickness Tool Log Results Summary ConocoPhillips Alaska, Inc. December 12, 2006 7629 1 4.5" 12.6 Ib L-80 NSCT Tubing 9.625" 40.0 Ib L-80 BTCM Surface Casing 16" 62.5 lb. Conductor Pipe H-40 Welded Well: Field: State: API No.: Top Log Intvl.: Bot. Log Intvl.: Top Log Intvl.: Bot. Log Intvl.: Top Log Intvl.: Bot. Log Intvl.: 1C-174 Kuparuk Alaska 50-029-23140-00 Surface 190 Ft. (MD) Surface 190 Ft. (MD) Surface 110 Ft. (MD) The MTT recordings indicate less metal volume over the interval of 16" conductor pipe (0'-107') relative to the interval of 9.625" (107'-190') surface casing. The tool appears to have recorded an inverted response (indicating less metal) at the bottom of 16" conductor pipe at 107', which has been noted when the volume of metal surrounding the tool exceeds the tool's capacity. Inverted collars are also recorded for the 9.625" casing in the top 107' of the log. We believe this to be the case at this point, where the extra metal in this interval is exceeding the tool's capabilities and causing an inversion in the tool's normal response. Above 107' and throughout the interval of 16" conductor, the tool continues to indicate less metal relative to the interval of 9.625" casing (below 107"). However, there are no obvious signal inversions for the 4.5" tubing collars throughout this interval. The extra distance from the tool's sensors (ofthe 16" casing relative to the 9.625" casing) and the combined pipe weight of the logged interval is exceeding the tool's normal recording capacity, resulting in an indication of less metal volume above 107'. I I I I The tool's response over the interval ofthe top 4.5" tubing joint generally indicates more metal than that in the second full joint of 4.5" tubing. There are no noted casing changes within this interval, pointing to the possibility that the top joint of 4.5" tubing may have different metallurgic properties than the tubing joints below it. Details of the tool recordings are included in this report. I I I I I U I..Œ- (903 -> OD-+ RECEIVED DEC 1 9 2006 Ah¡~~a Oil & Gas Cons. COOImi$$ìQr! Anchorage Pro.Active Diagnostic Services, Inc I P,O. Box 1369, Stafford, TX 77497 P!¡one: or 565-9085 Fa)<: (281) 565-1369 E-maí!: PDS(q~¡mernory¡og.con~' PnJÔllOe Sav F¡ejd Office Phone: 659··2307 Fax: 6.59-231 Lj I . . I INTERPRETATION OF MTT LOG RESULTS: I The total amount of metal sUffoundina the MTT in this loa interval exceeded the amount under which the tool can o/Jerate /Jro/J6rly. The true meanina of the recordinQs are unknown. and the data is /Jresented and discussed here only as a record of the tools res/JOnse under these conditions which are beyond its acce/Jtable o/Jeratina ranae. This data is also provided to compare to pipe's condition should it be excavated in the future. I I I I I I I I I I I I I I I Field Engineer: R. Richey & J. Halvorsen Analyst: M. Tahtouh & J. Burton Witness: C. Fitzpatrick I I 7749ì' I I I £~ Manetic Thickness T 10HZ Pass) PnoAcrivE DIAq"""",¡c SERvlc"", IN<::, Database File: d\warrior\data\1c-174\1c-174.db Dataset Pathname: 1Ohz.1 Presentation Format: 2SCALE-1 Dataset Creation: Wed Dee 1311:56:422006 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1150 -50 Delta Metal Loss (%) 50 12 MTTP01 (rad) 12 0 Line Speed (ftJmin) -200 -6.8 MTTP12 (rad) 3.2 I I II I I II I i ~- - -. t--^- ~,_.. - -- f--^. ^^- -^ -. f--- ~._^- - I y~^^, -20 I- --~. ---- - ^f-^^- "^--- I ^- --^ ( ^- ^- '- ~-~- -~ ^^-- .--- - - -^ ~..~ -10 --~. - - .^- -.^ Tree Line, Sp~e,-, I Hanger Pup Jt. - ---- f Inverted I I 9.625"..... .5" Collar_ -- -- Collar f-- ,I 10 i'\ f--- i5~ ~ '¡¡ ^^ f--^ -^- -^ ~ ^- T I - 4.5" I- --.-- -^^ f-- Ji. 1 '-.. 20 I ~ 'Þ- f-- f -tt - --:: - - ---.- e-.. -'^- ~ ,^... - - - : /I -. ^- -^^ - I !<- 30 ___m_ -. - .^-. 4.5',' Ci"aL -^ -^^ Pup Jt. -^- -^ ^- -~ 4. 5" Collar 40 '--~ e--- - Inverted ..- '-- 9 625" - -- '-- -- r~ ',^ ,^ Collar 50 í- -- 4.5" --.--- ;;.. =.:: ^- ~-,- f--- --^- - Jt. 2 -. -^ -~ - _._-~ ^^- '::- ~ -- I-- 60 t t__ ^- 1- -^- f-^~- ---- - -^^^ -- -'- f-- .- ^-. ^- _'M ~ --~- I 4. 5" Collar- - 70 I .. -^- ~- -.^ --., -^ -^- It I --- -. -- I- -' , ^ ^ J-l1 I I I I I I I I I I I I I I I I I c---- Inverted - ~ , 80 - ~,~ - .,~ ~' I-- ~ 't" I '\ f---.. '---+__ ~ 625" I ' ;;... -" 4.5" '- -_.~ Collar I-- Jt 3 --~. 90 ~I I ~ ~"~, I 100 u__ 4.5',' Collar --- '- - Bottom of 16" Conductor :s 110 I'i>. ~ ~~ :t 4.5" S Jt. 4 ~ ,)1 "!i I--- ..... ~9.625" Collar 120 -> -- j .. - - I ._u__ .. ~ --- ---- .. 1Q9 - .-= 4.5" Collar J I ~ - .. ~ ~ - '- 140 ~ - - - 1 4.5" - C._ ~---- Jt. 5 I ~ -- '~ ~ == ~ 150 - ,.. J- - 1-- . - ';C:A "'- f- - I- 11.5" Collar-- - _ _u I_ ....... - __WM~ -- .. - -- ~- I ;f ) 170 \ I I 1- <~ I 4.5" Jt 6 -~ I - ~ ---- f-- ..--....- --~ -- 180 ~ \ .- ... '- \. ~ 1 ¡ 1---'- "\ ~ f---- .--....-- f--- .. ~- -- ..-> "i.. : !--End of Log 190 - .... _ ,_----1 -50 Delta Metal Loss ('Yo) 50 2 MTTP01 (rad) 12 0 Line Speed (fUmin) -200 -6.8 MTTP12 (rad) 3.2 I I I I I I I I I I I I I I I I I I I KRU 1C-174 I 1"""II~ API: 500292314000 Well Tvoe: INJ Angle (â) TS: dea (â) TUBING SSSV Type: NIPPLE Orig 4/212003 Angle @ TD: 82 deg @ 12485 (0-7062, Completion: 00:4.500, 10:3.958) Annular Fluid: LastW/O: Rev Reason: Show PERFS SURFACE Reference Loa: 28' RKB Ref Log Date: Last Update: 8/212005 (0-7174, Last T aa: 12391' CTMD TO: 12485 ftKB 00:9.625, Wt:40.00) Last Tag Date: 10/24/2004 Gas Lift IINhlnÂ'nNr;:liWI44'~ I ndreliDummy Description Size Too Bottom ND Wt e I Thread Valve 1 LINER 5.500 7074 1 12485 I 12485 15.50 L-80 1 Hvdril511 (2504-2505, SLOTTED LINER 5.500 7333 I 12399 I 3865 15.50 I L-80 I Hvdril511 OD:5 ,968) ~RFACE I Size TOD I Bottom I ND I Wt 1 Grade I Thread I 9.625 0 I 7174 I 3726 I 40.00 I L-80 I BTC-MD IT..~I 16.000 I 0 1 110 I 110 I 62.50 I H-40 1 WELDED Too I Bottom I ND I Wt I Grade I Thread NIP 4.500 0 I 7062 1 3711 I 12.60 I L-80 1 NSCT (6300-6301, 00:5.630) Interval ND Zone Status Ft SPF Data TlIDe Comment 7333 - 12399 3748 - 3865 WS D,WS 5066 40 3/30/2003 Slotted Alternating 30' slotted liner C,WS Liner w/43' solid liner B,WS C,WS D,WS C,WS B,WS Liner NIP C,WS (7035-7048, D,WS 00:7,650) C,WSB SEAL ~!..i1't (7044-7045, MD IVD Man Man Type I VMfr I VType I VOD I Latch I Port I TRO I Date I Vlv 00:5.210) Mfr Run Cmnt .04 1920 CAMCO K~ 1 DMY 1 1.0 I BK-5 I 0.000 I 0 15/10/20031 ·:i....·....::\·"'·.i LinerXO NO TlIoe Descripúon 10 (7048-7051, 23 23 HANGER. GRAY ffiG HANGER, MCA TOP CONNECTOR 4.500 OD:7.000) 499 498 NIP 0 'DB' NIPPLE W/NO GO PROFILE 3.812 6300 3544 NIP 0 'DB' NIPPLE W/NO GO PROFILE 3.750 7044 3709 SEAL BAKER G-22 LOCATOR SEAL ASSEMBLY 3.870 Liner SBE Ipn...... r"l. "''''eålllò.:..t, " >IIN¡;::Q.I¡::;W¡::;,..RY (7051-7070, Depth NO Tvoe DescriotÎon ID 00:6.250) 7021 3706 Liner BAKER ZXP PACKER W/HR PROFILE 6.290 PACKER Liner PUP 7035 3707 Liner NIP RS NIPPLE 6.188 (7070-7074, 7048 3709 Liner XO CROSSOVER BUSHING 4.890 00:5,500) 7051 3709 Liner SBE BAKER SEAL BORE EXTENSION 4.750 7070 3712 Liner PUP L·80 HYDRILL 511 SOLlO 4.950 12399 3865 Liner BAKER INSERT PACKOFF 0.000 PACK OFF 12483 3876 Liner SHOE WEATHERFORD REAMER SHOE 4.950 LINER (7074-12485. -- 00:5.500, Wt15.50) Perf (7333-12399) Sl.OTTEO LINER (7333-12399. 00:5.500, Wt:15.50) - Liner SHOE 12483-12484, 00:5.500) ..tiI ... I I I I I I I I I I I I I I I I I - e RECEIVED DEC 0 9 2005 AI..J. n" n - - - 1. Operations Perfo'rr.ed: Abandon LJ Repair Well n Piug Perforations 0 Stimulate 0 'Öíher" .~ YVINJ to WAt; , SI r.hprJlOp. Alter Casing n Pull Tubing [] Perforate New Pool 0 Waiver D Time Extension L Change Approved Program 0 Ope rat. ShutdownD Perforate 0 Re-enter Suspended WeÙ 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory LJ ~1. 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23140-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 87' 1C-174 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk River Field I West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12485' feet true vertical 3876' feet Plugs (measured) Effective Depth measured 12483 feet Junk (measured) -~._- .. . '--- true vertical 3898 feet Casing Length Size MD -~ TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SURFACE 7087' 9-518" 7174' 3726' LINER 5411' 5-1/2" 12485' 3876' PROD. CASING 5066' 5-1/2" 12399' - 3865' . . Ef' PEe f (:; 2005 5<;ANN· ..-J - - Perforation depth: Measured depth: 7333'-12399' true vertical depth: 3748'-3865' RBDMS BFl DEC 09 2005 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7062' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 499' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-ßbl CasinQ Pressure Tubina Pressure Prior to well operation 10 965 Subsequent to operation 1736 585 965 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory [J Development U Service ~ Daily Report of Well Operations_X 16. Well Status after proposed work: Oil!:] GasD WAG[J GINJU WINJC] WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: .. C~ntact ," Robj¡rt D. \clristenr Pnnted "'me ~' . Title Production Engineering Technician ____. Signature X",">, I~ i 1 )1 '~¡:Ãt j . Phone 907-659-7535 Date 1~/O&,c9~ ..../ ,,....( :,\"".': """ I , OR!GI0J/J,L . . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS a( Form 10-404 Revised 04/2004 Submit Ongmal Only e e 1C-174 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/22/200sICommenced EOR WAG Injection ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test \"1\ÜŠ ~ - \'- \'-G'd(\, Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERA TOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska KR U 1 C 10/30/05 Greenwood/Arend AES ./" ft~ ~!flf Packer Depth Pretest Initial 15 Min. 30 Min. We1l1C-174 Type Inj. S TVD 3,706' Tubing 590 590 590 590 Interval 0 P.T.D. 2030270 Type test P Test psi 1500 Casing 0 3000 2960 2930 P/F P Notes: Support for MI injection pilot project OA NA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) 5tANNEr NO\J 1 7 2005 , ' 2005-1030_MIT_KRU_1C-174.xls Permit to Drill 2030270 MD ---. 12485 ----------- REQUIRED INFORMATION ----- ~/ i I Rpt i ~ I I Rpt I l!:Pt ~__ Well Cores/Samples Information: Name ~ f1'1~ ÀÛDq- DATA SUBMITTAL COMPLIANCE REPORT 5/2/2005 Well Name/No. KUPARUK RIV U WSAK 1C-174 Operator CONOCOPHILLlPS ALASKA INC ~ vi I AM,,"t J.. ~\1 3 API No. 50-029-23140-00-00 /~/¿""~---) ~. ND 3899 /' Completion Date 4/2/2003./ Current Status 1WINJ Mud Log No Name I nd uction/Resistivity Gamma Ray LIS Verification Gamma Ray I nd uction/Resistivity Cement Evaluation LIS Verification Injection Profile Directional Survey Directional Survey Completion Status 1WINJ Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR / Res Well Log Information: Log/ Electr Data Digital Dataset ~T E~ ~~/~~t_~umber J Log I ! og ~. C ~716 A~:g_ ~ (data taken from Logs Portion of Master Well Data Maint) --- Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 25 Blu 1 120 12485 Open 4/28/2003 25 Blu 120 12485 Open 4/28/2003 120 12485 Open 4/28/2003 25 Blu 120 12485 Open 4/28/2003 25 Blu 120 12485 Open 4/28/2003 A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 2/10/2003. 5 Col 6010 7006 Open 5/8/2003 120 12485 Open 4/28/2003 15 Blu 7250 12100 Case 9/28/2003 Injection Profile wlWelltec 0 218 Tractor '-' 1-2e""'" 12485 4/15/2003 0 ~ 12485 2/20/2004 Sample Interval Set Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 5/2/2005 Permit to Drill 2030270 Well Name/No. KUPARUK RIV U WSAK 1C-174 Operator CONOCOPHILLlPS ALASKA INC MD 12485 TVD 3899 Completion Date 4/2/2003 Completion Status 1WINJ ADDITIONAL INFORMATION Well Cored? Y /~ Daily History Received? Chips Received? .:X1J:L-- Formation Tops Analysis Received? ~ ---~-- Comments: Compliance Reviewed By: ~ Current Status 1WINJ QN (J/N Date: API No. 50-029-23140-00-00 UIC Y -- '3 ~ ~~~- '-~ Schlumbergel' NO. 2967 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth 09/25/03 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Field: Date BL Color 09/01/03 1 09/02103 1 09/05/03 1 08/01/03 1 08/02103 1 08/06/03 1 08/07/03 1 08/20/03 1 08/23/03 1 08/14/03 1 2X-14 1>;4 - I ~ PROD PROFILE/DEFT 2A-24 \ q ~ - \ l PROD PROFILE 3F-15 l'BJ=5'. -(y~ INJECTION PROFILE 35-24 fJ..O-:S -Q19 INJECTION PROFILE 35-09 .Ä. t:~ -~t? INJECTION PROFILE 3H-07 -1 ~"1 -~- t...:l INJECTION PROFILE 2K-11 ~R ,,5 5BHP SURVEY 1 D-1 03 ( Q2) 'C-,-_' j " INJECTION PROFILE 1C-174 _".i /~ V'" £f. INJECTION PROFILE 18-102 r90~m. 23432 U51T SIGNED~~'~ ~ v:.~, C' ~~ ""'-"Ý\. DATE: Kuparuk CD - ~ RoE(;EfVcû ~rp ~) 8 2~}(J{:i j).¡g3t~~3 cJji ¿ ::;~~ CU-¡;5. ~:;Grnr;Ü~on Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank yoü'. .. ~~.fic;¡ortgB ~~~ .~- Ç:. MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich DATE: July 12, 2003 Commissioner i ." 1\ {.~\~?SUBJECT: Mechanical Integrity Tests THRU: Jim Regg ~e.épl BPX P.I. Supervisor 1 C 17, 174 FROM: John H. Spaulding KRU Petroleum Inspector Kuparuk River Field NON· CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well 1 C-17 Type Inj. S TV.D. 6145 Tubing 2344 2455 2465 2464 Interval 4 P.TD. 1982240 Type test P Test psi 1536 Casi ng 1350 3125 3125 3125 P/F f Notes: Well 1 C-174 Type Inj. S TV.D. 3727 Tubing 1420 1412 1411 1412 Interval I P.T.D. 2030270 Type test P Test psi 932 Casing 1300 2500 2400 2400 P/F f Notes: Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casi ng P/F Notes: Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casi ng P/F Notes: Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year Cycle S = SALTWATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details I traveled to CP A' s KRU I C pad to witness the MITis on the above wells. Jared Brake was the CPA rep. today. The pretest pressures were observed and found to be stable. The standard annulus pressure tests were then perfonned with both wells meeting the AOGCC criteria for a successful MIT. M.I.T.'s performed: ~ Attachments: Number of Failures: º Total Time during tests: ~ cc: M IT report form 5/12/00 LG. 2003-0712_MIT _KRU_1C-174.Js.xls 7/18/2003 ) ) Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocJP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 June 10,2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 1 C-174 (APD # 203-027) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 1 C-17 4. If you have any questions regarding this matter, please contact me at 265-6830 or Steve Shultz at 263-4620. \ <--~- \ ~ Sincerely, R. Thomas Kuparuk Drilling Team leader CPAI Drilling RT/skad RECEi\/E;D JUN 1 3 7n~.i Afaska Oil & Gas Cons. ComrnL; ~¡an Anchorage ORIGINAL \ ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil D Gas U Plugged D Abandoned D 20AAC 25.105 No. of Completions _ GINJ EI 2. Operator Name: WINJ D WDSPL D ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 1458' FNL, 1129' FWL, Sec. 12, T11N, R10E, UM At Top Productive Horizon: 1870' FSL, 2231' FWL, Sec. 2, T11N, R10E, UM Total Depth: 1817' FSL, 1040' FWL, Sec. 35, T12N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 562135 y- TPI: x- 557929 y- Total Depth: x- 556691 y- 18. Directional Survey: Yes EI NoU 5968779 5972074 5977291 Zone-4 Zone-4 Zone-4 21. Logs Run: GRlRes 22. Suspended 0 WAG D 20AAC 25.110 Other 5. Date Comp., Susp., or Aband.: April 2, 2003 6. Date Spudded: March 12, 2003 7. Date TD Reached: March 29, 2003 8. KB Elevation (ft): 87' AMSL 9. Plug Back Depth (MD + TVD): 12483' MD 13898' TVD 10. Total Depth (MD + TVD): 12485' MD / 3899' TVD 11. Depth where SSSV set: Land Nipple @ 498' 19. Water Depth, if Offshore: N/A feet MSL / 1 b. Well Class: Development D Exploratory D Service EI Stratigraphic Test D 12. Permit to Drill Number: 203-027 I 13. API Number: 50-029-23140-00 14. Well Name and Number: 1 C-17 4 15. Field/Pool(s): Kuparuk River Field West Sak Oil Pool 16. Property Designation: ADL 25649 & 25638 17. Land Use Permit: ALK 467 & 463 20. Thickness of Permafrost: 2180' MD CASING SIZE GRADE B L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD Surface 110' 42" 43 sx ArcticCrete Surface 7169' 12.25" 100 sx AS III Lite, 288 sx Class G Neat 7021' 12485' 8.5" slotted liner WT. PER FT. 62.5# 40# 15.5# 16" 9.625" 5.5" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): slotter liner from 7021' - 12485' ~~~~C' :;::;I\~;;;'Ï:~:r'-¡o'7:-;-:1 Ie /" u..,. ¡~. I' ~ DATE ~ ~ Ý,'2.:ç> :ti ,~ ìlEi]JEJ ED ~," ~ ......d ^ _. ~ ¡,..........., 'f1""I'~~'C""""'''''~~~ 24. SIZE 4.5" AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 7063' PACKER SET (MD) 7021' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 26. Date First Injection June 8, 2003 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Injector Production for OIL-BBL GAS-MCF Test Period --> Calculated OIL-BBL Flow Tubing Casing Pressure press. psi 24-Hour Rate -> 27. WATER-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO CORE DATA OIL GRAVITY - API (corr) Submit core chips; if none, state "none". Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). K I:: C I:: ~ \1 F: " NONE RBDMS BFL f;Þ JUN172E Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE OR\G\NAL JUN 1 3 )nn1 A1aska Oi\ & Gas CGi!;::. Lt;f\h"¡-,¡SS:O;-; Anchorage Submit in duplicate 28. ) 29. ') GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. Ust intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1C-174 West Sak 0 West Sak C 7101' 7452' 3738' 3786' N/A RECEIVED JUN 1 3 2003 Alaska Oil & Ga" Co ~ p . ,)I T!;.\. uomrmssiol1 Anchorage 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: ,;; pt.-4teve Shultz 263-4620 Printed N~ R. ,Thomaj. Signature ( ~.--.a. \. \ ~ . Title: Phone Kuparuk Drilling Team Leader Date ~('"(^/o' Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 ORIGINAL ) ) Legal Well Name: 1 C-17 4 Common Well Name: 1 C-17 4 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From -To Hours Code . Sub . Code 3/11/2003 01 :30 - 12:00 10.50 MOVE MOVE MOVE 12:00 - 15:00 3.00 MOVE RURD MOVE 15:00 - 16:30 1.50 DRILL RIRD SURFAC 16:30 - 22:00 5.50 DRILL RIRD SURFAC 22:00 - 00:00 2.00 DRILL PULD SURFAC 3/12/2003 00:00 - 00:30 0.50 DRILL RIRD SURFAC 00:30 - 01 :00 0.50 DRILL RIRD SURFAC 01 :00 - 01 :15 0.25 DRILL SFTY SURFAC 01:15 - 09:00 7.75 DRILL PULD SURFAC 09:00 - 09:30 0.50 DRILL PULD SURFAC 09:30 - 10:15 0.75 DRILL PULD SURFAC 10:15 - 12:00 1.75 DRILL PULD SURFAC 12:00 - 13:00 1.00 DRILL SFTY SURFAC 13:00 - 14:30 1.50 DRILL PULD SURFAC 14:30 - 14:45 0.25 DRILL SFTY SURFAC 14:45 - 15:00 0.25 DRILL CIRC SURFAC Start: 3/11/2003 Rig Release: Rig Number: Spud Date: 3/12/2003 End: Group: 12:00 - 20:15 Move Rig from 1C-190 to 1C-174 (320' NW dn well row) Spot sub centered over well - Set pipe sheds - Spot pits, pump, engine & utility modules. H/U all service inconnects between modules. ........Rig Accept 3:00 PM 3/11/03 ........ Install 22" air boot on circulating pan under rotary. Start mixing Spud Mud. - Start nipple up Diverter Load all Directional & MWD tools in pipe shed to warm up. Load, drift & strap 210 jts 5" DP into pipe shed - cIa TD saver sub, grabbs & stabbing guide over to 5" DP Finish changing TD grabs over to 5". cia all handing equip on rig floor - Remove 4" tools & subs from rig floor. PJSM - Review P/U procedure - Review pinch point & hazards of task. P/U & Std Bk in derrick 70 stds 5" DP ( 6501') - P/U & Std Bk in derrick 10 stds HWDP wi jars. P/U & Std Bk 1 std 8" Monel DCs Pull BHA stabs and tools to Rig floor. P/U BHA #1 - P/U Motor, M/U bit,stab. Pre Spud Meeting with Both crews and all contractors. Review well objectives and drilling risks. M/U MWD -Orient to motor- Program MWD - RIH wi std 8" monels - Tag @ 107' PJSM - Pre job spill check - Review spill plan & prevention. Flood conductor and flow lines - Check complete mud system for leaks - Fuction Test diverter - Knife valve closed 5 sec, Bag seal in 18 sec, Koomey unit ,200 psi build 31 sec, full build to 3,000 psi in 3 min -10 sec. AOGCC rep Jeff Jones waived witness of Div fuction test. 9.00 DRILL DRLG SURFAC Drlg, Slide & Survey 107' to 986' MD, 966' TVD ART 2.4 hrs, AST 3.9 hrs. WOB 5/25k, RPMs 60, PRate 120spm, 509gpm, PP 1000 psi, Up wt 80k, Dn wt 85k, Rot wt 83k, Trq on bttm 2-6 ft-Ibs, off bttm 2 ft-Ibs. Mud wt 8.8+, Vis 200. Small show of gas hydrates from 1000' to 1150'. Drilling well - No hole problems. 1.50 DRILL DRLG SURFAC Drlg,Slide & Survey 12.25" hole 986' to 1170' MD, 1141' TVD -ADT 0.5 hrs, AST 0.9, WOB 20/30k, RPMs 60, PR 120spm, FR 552gpm, PP 1600psi, Up wt 94, Dn wt 85k, Rot wt 89k. ....Note.... Small to moderate show of gas hydrates 1000' to 1150'. Mix 1 drum driltreat to enhance mudlgas seperation. 1.00 DRILL REAM SURFAC Ream 1080' to 1170' to reduce DLS per Baker Inteq DD (Before 7.89 degree, After 4.22 degree) 9.50 DRILL DRLG SURFAC Drlg,Slide & Survey 12.25" hole 1170' to 1942' MD, 1675' TVD - ART 5.9 hrs, AST 5.2 hrs, WOB 20/30k, RPMs 60, PR 130spm, FR 552gpm, PP 1640psi, Up wt 100, Dn wt 88k, Rot wt 92k.....Note.... Had small to moderate gas hydrates @ 1593'. Hydrates deminished after 50'-60'. 8.25 DRILL DRLG SURFAC Drlg,Slide & Survey 12.25" hole 1942' to 3029' MD, 2165' TVD- ADT 3.7 hrs, AST 1.4 hrs WOB 20/30k, RPMs 60, PR 130spm, FR 552gpm, PP 1640psi, Up wt 100, Dn wt 88k, Rot wt 92k. Up wt 110k, Dn wt 82k, Rot 90k,Trq on bbm 5-9 ft-Ibs, off bttm 4-7 ft-Ibs. 1.75 DRILL CIRC SURFAC Pump Wt barofiber sweep(12.2ppg) - PR 140spm, FR 594gpm, 120 RPMs - Circu BU , Saw a 25% increase in cutting on BU. On BU most cutting returns were ground up 50/50% cutting/barolift wi a good 15:00 - 00:00 3/13/2003 00:00 - 01 :30 01 :30 - 02:30 02:30 - 12:00 20: 15 - 22:00 Printed: 4/24/2003 9:42:23 AM ) ') amount of sand. After the sweep passed it was noted that we did recover some 3/4" rock & gravel. The sweep seem to work well. Circu until clean per Baroid rep. TOH on elevators- Tight @ 2536' 30k overpull. Back ream 2566' to 2009' - 80 RPMs, PR 110spm ,467gpm. No excess Troq, No pack off problems while reaming. TOH on elevators to 1452' - No overpull, No swab Pump OOH, 500gpm, 1050psi - No excess overpull. TOH Std Bk HWDP & Std monel DCs -UD BHA #1 Drain motor, Bk bit, Plug in Ck MWD Data, UD MWD,LWD & Motor. P/U BHA#2 - P/U AUTOTRAK ,plug in & program, float sub, stab & std monel DCs M/U 1 Std HWDP and pulse test tools "OK" TIH - Tight spots 950' - 1950' Wash & Ream until clean 120 spm, 509 gpm, 80 RPMs CBU - Survey - Dn link tool Drlg 12.25" hole w/AutoTrak 3029' - 3101' MD (2200 TVD), ADT 2.0 hrs WOB 10/35k, RPMs 140, PR 185 spm, 785 gpm, PP 2020 psi. When first on bttm drlg, bit seemed to be balled up.Very slow ( 6-8 fph)ROP.Worked to clean bit 20-30 min. Pumped 20 bbl CONDET pill and helped clean up bit. 12.00 DRILL DRLG SURFAC Drlg 12.25" hole w/AutoTrak 3101' - 4480' MD(2818' TVD), ART 6.7 hrs AST 0.0 hrs, WOB 10/35k, RPMs 140, PR 185 spm, 785 gpm, PP 2500 psi. Up wt 145k, Dn wt 75k, Rot wt 96k, Torq on bttm 8-17k, Off bttm 13k. Ghost reamer 2172 ' behind the bit between stds # 12 - #13 of 5" DP. 12.00 DRILL DRLG SURFAC Drlg & Survey 12.25 hole wI AutoTrak 4480' to 5233' MD (3130' TVD) ART 6.2 hrs, WOB 25-35k, RPMs 170, PR 184 spm, 780 gpm,PP 2650 psi, Up wt 155k, Dn wt 85, Rot wt 107K. Ghost reamer 2172' behind the bit. 10.50 DRILL DRLG SURFAC Drlg 12.25" hole w/AutoTrak 5233' - 6265' MD (3565' TVD), ART 7.4 hrs AST 0.0 hrs, WOB 10/35k, RPMs 140, PR 185 spm, 785 gpm, PP 2500 psi. Up wt 145k, Dn wt 75k, Rot wt 96k, Torq on bttm 8-17k, Off bttm 13k. Ghost reamer 2172 ' behind the bit. Drlg 6261' to 6265' - P/U off bttm - DN link AutoTrak - Blew Popoff on mud pump #2. Recip DP 8' & pump w/#1 mud pump @ 92 spm. Repair Popoff on #2 mud pump. Install spare rebuilt complete valve. Bring both pumps back on line - Attempt to down link AutoTrak - Pipe sticking - TD failed - Will not rotate Stuck @ 6261 ' - Top Drive will not rotate(Mechanicall) PR 120 spm, Up wt 170k - Work up slowly 60k to 100k overpull wI 4 hits on jars. Pump 25 bbl un-weighted gel,barazan & pac-L pill & circu to bit. With pill around bit, Jar up 100k - Pipe free, Circu 120 spm, 90 RPMs - Can not Std Bk std because TD will not rotate -Circu & recip string until Electrician fixed Top Drive ( Low oil shutdown switch malfuctioned) Con't trouble shoot Top Drive. Will not rotate. (Low oil lock out switch tripped ). Circu @ 80 spm, 340 gpm, PP 750 psi Drlg & Survey 12.25" hole wI AutoTrak 6265' to 6823' MD (3699' TVD) WOB 15-35K, RPMs 170, PR 160 spm, 675 gpm. Had Power Outage- Hi line breaker tripped - Not sure of reason? May have been power surge or hi amps? Electrician is trouble shooting to find cause. Re-start equip, Re-boot all Baker MWD computers. Legal Well Name: 1 C-17 4 Common Well Name: 1 C-17 4 Event Name: ROT - DRILLING Contractor Name: n 1334@ ppco.com Rig Name: Doyon 141 Date From-To Hours. Code Sub Phase COde 3/13/2003 20:15 - 22:00 1.75 DRILL CIRC SURFAC 22:00 - 22:30 0.50 DRILL TRIP SURFAC 22:30 - 23:00 0.50 DRILL REAM SURFAC 23:00 - 00:00 1.00 DRILL TRIP SURFAC 3/14/2003 00:00 - 00:30 0.50 DRILL TRIP SURFAC 00:30 - 02:15 1.75 DRILL PULD SURFAC 02: 15 - 05:00 2.75 DRILL PULD SURFAC 05:00 - 05:30 0.50 DRILL DEOT SURFAC 05:30 - 08:15 2.75 DRILL TRIP SURFAC 08:15 - 09:30 1.25 DRILL CIRC SURFAC 09:30 - 12:00 2.50 DRILL DRLG SURFAC 12:00 - 00:00 3/15/2003 00:00 - 12:00 12:00 - 22:30 22:30 - 22:45 0.25 DRILL DRLG SURFAC 22:45 - 23:00 0.25 RIGMNT RGRP SURFAC 23:00 - 23:30 0.50 DRILL CIRC SURFAC 23:30 - 00:00 0.50 DRILL DRLG SURFAC 3/16/2003 00:00 - 00:30 0.50 RIGMNT RGRP SURFAC 00:30 - 08:45 8.25 DRILL DRLG SURFAC 08:45 - 09:45 1.00 RIGMNT RGRP SURFAC Start: 3/11/2003 Rig Release: Rig Number: Spud Date: 3/12/2003 End: Group: Printed: 4/24/2003 9:42:23 AM ) ) . .C()ndb()Phitlip~ Alaska Operations .SumrnaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-17 4 1 C-17 4 ROT - DRILLING n1334@ppco.com Doyon 141 Date Fröm·..To Hours Code· Sub Code 3/16/2003 09:45 - 12:00 2.25 DRILL DRLG SURFAC Start: 3/11/2003 Rig Release: Rig Number: Spud Date: 3/12/2003 End: Group: Description of Qperati()ns Drlg & Survey 12.25" hole wI AutoTrak 6823' to 6906' MD (3711' TVD) ART 7.5 hrs, WOB 20-35K, RPMs 170, PR 160 spm, PP 2600, 675 gpm, Up wt 165k, On wt 84k, Rot wt 115k, Troq on bttm 15-20 ft-Ibs, 13-15 ft-Ib, Mud wt 10.0 ppg, Vis 92. 6.00 DRILL DRLG SURFAC Drlg & Survey 12.25" hole wI AutoTrak 6906' to 7174' MD (3748' TVD) ART 5.2 hrs, WOB 10-35K, RPMs 170, PR 160 spm, 675 gpm, PP 2600 psi, Up wt 165k, On wt 82k, Rot wt 108k, Troq on bttm 15-18 ft-Ibs, 13-14 ft-Ib, Mud wt 10.0 ppg, Vis 99. TD per on site geologist pick. 2.50 DRILL CIRC SURFAC Pump Wt barolift sweep @ 13.6 ppg (0.2 ppb barolift) - PG 160 spm, 675 gpm, RPMs 120, Had a 25% increase in cutting on BU. - Circu hole clean per Baroid mud rep. Observe well - Blow dn TD 1.00 DRILL WIPR SURFAC TOH on elevators - Pull out to 6786'. At this point saw 30k overpull, drop back down to 6816' - M/U TD & pump out of hole f/6816' to 6538', PR 80 spm, 297 gpm, PP 1050psi. Set stand #60 back. When we came off the slips on std #59 the string was Stuck. 2.50 DRILL DRLG SURFAC Work Stuck Pipe @ 6538' ( 73.4 degree) - Attempt to jar down - No success -Jar does not hit - Can feel bump action only - Wt transfer to jar minimal to light - Pump unweighted 25 bbl gel,barazan pill, (225' coverage) Work pipe,Torq & slack off wt, No success - Spoted 25 bbl EZ glide pill( 225' coverage), Work pipe, Torq & slack off wt, No succes. UWT=170K, Max pu1l300K. Max TQ applied = 20K ft-Ib. Work Stuck Pipe @ 6538' ( 73.4 degree) - Spoted 25 bbl EZ glide pill (225' coverage), Con't to work pipe, Torq & slack off wt, No succes. PU wt =170K, Max pull 375K. Max SOW 40k Work Stuck pipe - Let lube pill soak ( Attempt to torg and SOW) Max torq applied 20k, Max SOW string wt to 40k ** Confer with West Sak develoment group. Work Stuck pipe - Off load 300 bbls of 10.0ppg mud onto Vac truck for storage. Work Stuck pipe - Reduce mud wt from 10.0 ppg to 9.8 ppg - When 9.8 ppg surface to surface, shut down & Monitor well, "Static". Work Stuck pipe - Reduce mud wt from 9.8 ppg to 9.6 ppg - When 9.6 ppg surface to surface, shut down & Monitor well, "Static". Work pipe, Max UPwt applied 375k, Max SOW string wt to 40k (blocks 35k), Max torq applied 20k. 2.50 FISH JAR SURFAC Work Stuck pipe - Reduce mud wt from 9.6 ppg to 9.4 ppg - When 9.4 ppg from surface to surface, Work pipe, Max UPwt applied 400k, Max SOW string wt to 40k( blocks 35k), Max torq applied 20k 1.50 FISH PULD SURFAC Monitor well - Baker Fishing P/U surface jars - Work Stuck pipe - Torq and slack off - Max SOW string wt to 40k ( Blocks 35k)- Had 8-9 good hits down with surface jars before Baker surface jars failed (after 25-30 total hits) UD Surface jars - CBU to evaluate 9.4 ppg mud wt. - Work stuck pipe. After conferring wI West Sak deveolment group it was decided to drop mud wt from 9.4 ppg to 9.2 ppg. Work Stuck pipe - Make ready Enviro Spot pill. wI 9.2 ppg surface to surface, Monitor well - "Static" - Work pipe Spot 46 bbl Enviro Spot pill- (Pill @ 9.2 ppg = 31 bbls diesel, 13.5 water, 5.2 bbls Enviro Spot, 100 (50 Ib) sxs barite. Displaced pill putting 18 bbls out side string & leaving 28 bbls in DP. The 18 bbls out side gave us 183' coverage. Top of 8" tools 6396' I top of pill @ 6355' 0.75 FISH JAR SURFAC Monitor well closely "Static" - Let Enviro pill soak - Move 1 bbl fluid 12:00 - 18:00 18:00 - 20:30 20:30 - 21 :30 21 :30 - 00:00 3/17/2003 00:00 - 01 :30 1.50 FISH JAR SURFAC 01 :30 - 04:00 2.50 FISH JAR SURFAC 04:00 - 05:00 1.00 FISH JAR SURFAC 05:00 - 08:30 3.50 FISH JAR SURFAC 08:30 - 12:00 3.50 FISH JAR SURFAC 12:00 - 14:30 14:30 - 16:00 16:00 - 17:30 1.50 FISH PULD SURFAC 17:30 - 20:30 3.00 FISH JAR SURFAC 20:30 - 21 :30 1.00 FISH JAR SURFAC 21 :30 - 21 :45 0.25 FISH CIRC SURFAC 21 :45 - 22:30 Printed: 4/24/2003 9:42:23 AM ) ) ConocoPhillipsAlpskä Oper~tions ..$UmrnaryReporf Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-17 4 1 C-17 4 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 3/11/2003 Rig Release: Rig Number: Spud Date: 3/12/2003 End: Group: Date From· - To Hours·' Code 3/17/2003 21 :45 - 22:30 0.75 FISH JAR SURFAC every 15 min for 2 hrs and then 1 bbl per hr. ( 22 hrs fluid total)- Blow dn TD each time. 22:30 - 23:00 0.50 FISH JAR SURFAC Attempt to jar dn - Slack off string wt to max 40k (blocks 35k)- NO progress 23:00 - 00:00 1.00 FISH JAR SURFAC Monitor well - Let pill soak - Work pipe lightly each hour. 3/18/2003 00:00 - 13:30 13.50 FISH JAR SURFAC Displace envirospot pill @ 1 bph-allow to soak-work stuck pipe. 13:30 - 14:30 1.00 FISH JAR SURFAC Make up surface jars & work stuck pipe. 14:30 - 15:00 0.50 FISH PULD SURFAC Lay down surface jars. 15:00 - 00:00 9.00 FISH JAR SURFAC Displace envirospot pill @ 1 bph While working stuck pipe. Prepare injection skid for displacing & injecting envirospot pill. 3/19/2003 00:00 - 02:30 2.50 FISH JAR SURFAC Pump unweighted sweep & circ. envirospot pill out of hole-spot 75 bbls. steel seal pill on bottom-working stuck pipe continuesly. 02:30 - 17:00 14.50 FISH ELlN SURFAC PJSM=rig up sws-make up & run in hole wI free point-stuck free point in top of dc,s-pull free & poh-change out free point tool & rih-pipe free @ 6362-1 % free @ top of dc,s @ 6395'. poh wI free point. 17:00 - 22:30 5.50 FISH ELlN SURFAC Rig up string shot @ 400 grains-rih-work pipe-put 5 rounds reverse torque in dp & fire string shot-back off @ 6362' dpm-poh-Iay down sws tools. 22:30 - 00:00 1.50 FISH CIRC SURFAC Circ.-clean hole @ 140 spm-90 rpm-1370 PP. 3/20/2003 00:00 - 00:30 0.50 FISH CIRC SURFAC Circ. & clean hole @ 140 spm-90 rpm-1370 PP. 00:30 - 04:00 3.50 FISH TRIP SURFAC Observe well-pump pill & poh for washpipe. (tight @ 1120' wI ghost reamer 30k overpull). 04:00 - 05:00 1.00 FISH OTHR SURFAC Cut & slip 85' drlg. line. 05:00 - 06:00 1.00 FISH OTHR SURFAC Service rig-adjust brakes-check out top drive. 06:00 - 08:00 2.00 FISH PULD SURFAC Pick up fishing & handling tools-make up 4 jts. 9 5/8" washpipe wI 12 1/8" shoe. 08:00 - 10:00 2.00 FISH TRIP SURFAC RIH to 3160'. 10:00 - 16:00 6.00 FISH WASH SURFAC Wash & ream from 3160' to top of fish @ 6362'. 16:00 - 19:30 3.50 FISH WASH SURFAC Wash over fish from 6362' to 6485'. PUW 165k SOW 80k RW 110k TQ 13-18k. SPM 120 PP 1150#. 19:30 - 20:00 0.50 FISH OTHR SURFAC Push fish to 6575' top of fish. 20:00 - 21 :30 1.50 FISH CIRC SURFAC Circ. & condition hole for trip out. 21 :30 - 00:00 2.50 FISH TRIP SURFAC Pump out of hole to 6300'-observe well-pump pill-blow down top drive-poh to 5464'-hole quit taking fluid-25 to 40k overpull. POH pumping out of hole. 3/21/2003 00:00 - 05:00 5.00 FISH TRIP SURFAC Pump out of hole from 4906' to 2862' & poh to washpipe. 05:00 - 06:30 1.50 FISH PULD SURFAC Lay down 4 jts. 9 5/8" wash pipe. Clear floor. 06:30 - 09:30 3.00 FISH TRIP SURFAC Make up fishing assembly & rih to 6450'. 09:30 - 11 :00 1.50 FISH CIRC SURFAC Wash to 6540' & cbu-clean hole. 11 :00 - 16:00 5.00 FISH FISH SURFAC Chase fish to 6700' & screw into same-poh-pump thru tight spots @ 6400'-6300' -5320 & 3150'. 16:00 - 19:15 3.25 FISH PULD SURFAC Lay down fishing tools & fish. 100% recovery on fish. Clear floor. 19:15 - 19:45 0.50 FISH OTHR SURFAC Service top drive & blocks. 19:45 - 20:45 1.00 FISH OTHR SURFAC Make up 12 1/4" hole opener & bha. 20:45 - 23:30 2.75 FISH TRIP SURFAC RIH to 5753' (worked thru tight spot @ 3647') 23:30 - 00:00 0.50 FISH OTHR SURFAC Wash & ream thru tight spots from 5753' to 5846'. 3/22/2003 00:00 - 03:30 3.50 FISH OTHR SURFAC Wash & ream from 5846' to 7174'. 03:30 - 07:00 3.50 FISH CIRC SURFAC Circ. condo mud & hole for 9 5/8" csg. 07:00 - 08:00 1.00 FISH TRIP SURFAC Observe well & poh wet to 6217'. 08:00 - 11 :00 3.00 FISH TRIP SURFAC Pump pill & poh. 11 :00 - 13:00 2.00 CASE RURD SURFAC Clear floor & rig up to run 9 5/8" csg. 13:00 - 13:30 0.50 CASE SFTY SURFAC PJSM wI csg. & rig crews & co. rep. 13:30 - 19:00 5.50 CASE RUNC SURFAC Run 90 jts. 95/8" 40# L-80 BTCM csg. to 3400'. Printed: 4/24/2003 9:42:23 AM ') ) Legal Well Name: 1 C-17 4 Common Well Name: 1 C-17 4 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date Sub Code 3/22/2003 19:00 - 19:45 0.75 CASE CIRC SURFAC 19:45 - 22:30 2.75 CASE RUNC SURFAC 22:30 - 00:00 1.50 CASE CIRC SURFAC 3/23/2003 00:00 - 01 :30 1.50 CASE RUNC SURFAC 01 :30 - 02:00 0.50 CASE RURD SURFAC 02:00 - 06:00 4.00 CASE CIRC SURFAC 06:00 - 09:30 3.50 CEMENT PUMP SURFAC 09:30 - 10:30 1.00 CEMENT DISP SURFAC 10:30 - 12:00 1.50 CEMENT RURD SURFAC 12:00 - 12:15 0.25 CEMENT SFTY SURFAC 12:15 - 14:15 2.00 CEMENT RURD SURFAC 14:15 - 15:15 1.00 CEMENT RURD SURFAC 15:15 - 19:00 3.75 CEMENT RURD SURFAC 19:00 - 20:30 1.50 CEMENT RURD SURFAC 20:30 - 00:00 3.50 CEMENT SEaT SURFAC 3/24/2003 00:00 - 00:30 0.50 CEMENT SEaT SURFAC 00:30 - 01 :30 1.00 CEMENT SEaT SURFAC 01 :30 - 02:30 1.00 CEMENT OTHR SURFAC 02:30 - 03:30 1.00 CEMENTOTHR SURFAC 03:30 - 04:00 0.50 CEMENTOTHR SURFAC 04:00 - 09:30 5.50 CEMENT TRIP SURFAC 09:30 - 10:30 1.00 CEMENTOTHR SURFAC 10:30 - 11 :30 1.00 CEMENT SEaT SURFAC 11 :30 - 14:30 3.00 CEMENT DSHO SURFAC 14:30 - 15:30 1.00 DRILL CIRC PROD 15:30 - 16:30 1.00 DRILL FIT PROD 16:30 - 20:00 3.50 DRILL CIRC PROD 20:00 - 21 :30 1.50 DRILL DRLH PROD 21 :30 - 23:00 1.50 DRILL OTHR PROD 23:00 - 00:00 1.00 DRILL DRLH PROD Start: 3/11/2003 Rig Release: Rig Number: Spud Date: 3/12/2003 End: Group: 3/25/2003 24.00 DRILL DRLG PROD 00:00 - 00:00 3/26/2003 00:00 - 13:30 13.50 DRILL DRLG PROD 13:30 - 15:00 1.50 DRILL DEOT PROD 15:00 - 18:00 3.00 DRILL DRLG PROD 18:00 - 19:30 1.50 DRILL CIRC PROD 19:30 - 00:00 4.50 DRILL TRIP PROD 3/27/2003 00:00 - 01 :30 1.50 DRILL TRIP PROD 01 :30 - 02:00 0.50 DRILL PULD PROD 02:00 - 03:30 1.50 DRILL PULD PROD 03:30 - 07:30 4.00 DRILL TRIP PROD 07:30 - 09:30 2.00 DRILL REAM PROD Description' of Operations · CBU @ 5.5 bpm 220#. Run 73 jts. 95/8" csg. to 6200'. CBU @ 5.5 bpm 350#. PUW 295k SOW 63k. Finish running 187 jts. 95/8" 40# L-80 BTCM Csg. from 6200' to 7167'. Lay down fill up tool & make up cement head. Circ.-condition mud & hole for cementing-rig up dowel!. Pump 10 bbls. CW100-test lines to 3500#-pump 60 bbls. CW100-50 bbls. mud push-drop bottom plug-pump 890 bbls. lead cement-60 bbls. tail cement. Kick out top plug w/1 0 bbls. water. Displace cement wI mud @ 9 BPM bump plug on calculated strokes 500# over-bleed off-floats held. Clear floor-lay down landing jt. & flush diverter system. PJSM on rigging down diverter. Nipple down diverter system & wash out annular preventer. Orient & nipple up tbg. head-test to 5000# 10 mins. Nipple up bope. Change out bottom rams from 4" to 5"-change out bails on top drive. Test bope-(witness test waived by John Crisp AOGCC) Finish test bope 3500# hi-250# 10. Test all bope. Pull test plug & install wear ring. Make up autotrak & initialize mwd. Make up bha #6. Shallow test autotrak. RIH picking up 162 jts. 5" dp to 6929'. Cut & slip 160' drlg. line. Rig up & test 9 5/8" csg. to 1500# 30 mins. Chart same. Wash from 6929'-drill plugs-float collar-firm cement-shoe & 20' new hole. Displace old mud wI gem clay seal mud. Rig up fit test equipment & test to 13.0# emw. Circ. & condition mud. Drlg. from 7194' to 7298'. Circ. Establish pwd baseline test. Drlg. horizontal undulated hole from 7298' to 7394'. PUW 181k SOW 70k RW 108k TO on 12-16k off16k RPM 120 SPM 135 GPM 550 ADT 2.4 SPR #1 20 spm 250# 40 spm 410 SPR #2 20 spm 160# 40 spm 280#. TVD 3778'. Drlg. horizontal undulated hole from 7394' to 8598'. POW 145k SOW 76k RW 104k TO 15k on 12k off ADT 18.1 SPM 140 PP 2150 GPM 592. SPR #1 20 spm 270# 40 spm 420# SPR #2 20 spm 200# 40 spm 340#. Drlg. Horizontal undulating hole from 8598' to 9465'. PUW 145k SOW 65k RW 105k TO on 15k Off 13k SPR #1 20 spm 31040 spm 510 #2 20 spm 220 40 spm 370#. Diagnose autotrak sleeve rotation-near bit inclination. Drlg. Horizontal undulated hole from 9465' to 9526'. CBU X 2. Observe well poh to shoe (hole in good condition) Pump pill & poh. POH to Check Failed AutoTrak. Lay down AutoTrak. Make up new AutoTrak & initialize. BHA #7. RIH to 9349'. Wash & ream hole from 9349' to 9526'. Printed: 4/24/2003 9:42:23 AM ') ) Legal Well Name: 1 C-17 4 Common Well Name: 1 C-17 4 Spud Date: 3/12/2003 Event Name: ROT - DRILLING Start: 3/11/2003 End: Contractor Name: n1334@ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number: Date From-To HoUrs .' Code Sub Description öf Operations CÖde 3/27/2003 09:30 - 00:00 14.50 DRILL DRLG PROD Drlg. Horizontal Undulated hole from 9526' to 10413'. TVD 3868'. PUW 132k SOW 80k RW 106k TQ on 11-13k off 10k RPM 140 SPM 140 PP 2160# ADT 10.3 hrs. GPM 600 SPR #1 20 spm 350# 40 spm 550# #2 20 spm 25040 spm 430# MW 9.1 Vis 49. 3/28/2003 00:00 - 00:00 24.00 DRILL DRLG PROD Drlg. Horizontal undulated hole from 10413' to 12032'. (TVD 3844') POW 136k SOW 75k RW 1 02k TO on 13k off 10k SPM 140 PP 2000# SPR #1 20 SPM 360# 40 SPM 550# #2 20 SPM 280# 40 SPM 470# ADT 16.5 hrs. MW 9.1# Vis 48. WOB 5/15k GPM 600. 3/29/2003 00:00 - 07:00 7.00 DRILL DRLG PROD Drlg. Horizontal Undulating Hole from 12032' to 12485'. ADT 4.5 hrs. PUW 150k SOW 82k RW 115k TO on 13k off 10k WOB 5/1 Ok RPM 140 SPM 130 GPM 550 PP 2000# TVD 3899'. MW 9.2# VIS 48. 07:00 - 09:30 2.50 DRILL CIRC PROD Circ. hole clean Pump weighted sweep. 09:30 - 18:30 9.00 DRILL TRIP PROD Observe well-poh pump out to 7115' @ drlg. rate (Back Ream) 18:30 - 20:00 1.50 DRILL CIRC PROD Circ. hole clean @ 7115' & spot EP Lube pill. 20:00 - 21 :00 1.00 DRILL OTHR PROD Slip & cut drlg. line. 21 :00 - 00:00 3.00 DRILL TRIP PROD POH to BHA. 3/30/2003 00:00 - 02:00 2.00 DRILL DRLG PROD Lay down BHA #7 & download autotrak. 02:00 - 03:00 1.00 CASE SFTY PROD PJSM-Clear floor & rig up to run 5.5" Liner. 03:00 - 07:00 4.00 CASE PULR PROD Pick up 95 jts. 5.5" 15.50# L-80 Hydril 511 Solid liner & 30 jts. Slotted liner. 07:00 - 08:00 1.00 CASE SFTY PROD PJSM-Rig up to run 3.5" inner string. 08:00 - 14:00 6.00 CASE PULR PROD Pick up & run 170 jts. 3.5" 9.2# Hydril511 inner wash string. 14:00 - 17:00 3.00 CASE OTHR PROD PJSM-Pick up packer-hanger & pups. 17:00 - 19:00 2.00 CASE RUNL PROD Run liner in hole on 5" dp. to shoe @ 7168'. 19:00 - 20:00 1.00 CASE CIRC PROD Circ. capacity of dp & inner string @ 650# PP & 4 BPM. 20:00 - 22:30 2.50 CASE RUNL PROD RIH wI 5.5" Liner on 5" dp to 12485' No Problems. r- 22:30 - 00:00 1.50 CASE CIRC PROD Circ. outer annulus wI 9.0# brine-full returns-circ. @ 7.5 bpm 1500# as per baker rep. 3/31/2003 00:00 - 04:30 4.50 CASE CIRC PROD Circ. Displace 8 1/2" X 5.5" annular & 9 5/8" X 5" annular wI 9.0# brine @ 7.5 bpm 1500#. Drop ball & set hanger-packer. Ball seated pressured up to 600# & pumped by. Increased pressure by pump speed to set hanger & packer. 04:30 - 05:00 0.50 CASE DEOT PROD Test 9 5/8" X 5" annulus 2500# 10 mins. ok. 05:00 - 06:30 1.50 CASE CIRC PROD Unsting from packoff & displace 4.5" X 5.5" annulus wI 9.0# brine. 06:30 - 13:00 6.50 CASE OTHR PROD POH laying down 5" dp & liner running tool. (Left 3.5" inner string in hole) 13:00 - 18:30 5.50 CASE DEOT PROD Pull wear ring-set test plug-test bope 250-3500#-rig down test equip.-pull test plug & run wear ring. (Witness test waived by Jeff Jones AOGCC) 18:30 - 21 :30 3.00 FISH PULD PROD Pick up & make up Baker fishing assembly. 21 :30 - 00:00 2.50 FISH TRIP PROD RIH wI fishing tools wI 5" dp. 4/1/2003 00:00 - 02:00 2.00 FISH TRIP PROD Con't TIH picking up 5" DP singles from pipe shed, wI fishing assy. Tag fish @ 6810' Up wt 120k, Dn wt 91k 02:00 - 02: 15 0.25 FISH FISH PROD Screw into fish, Up wt 134k, Dn wt 77k - Pressure up to 2000 psi to verify fish "OK" 02:15 - 02:30 0.25 FISH TRIP PROD Monitor well - Blow dn Top Drive 02:30 - 06:00 3.50 FISH TRIP PROD TOH to fishing tools 06:00 - 07:30 1.50 FISH PULD PROD UD fishing tools - Clear from rig floor 07:30 - 07:45 0.25 FISH SFTY PROD PJSM on laying dn wash string 07:45 - 08:00 0.25 CMPL TN PULD PROD R/U to UD 3.5" wash string 08:00 - 12:00 4.00 CMPL TN PULD PROD UD 3.5" Tbg wash string 12:00 - 12:15 0.25 CMPL TN SFTY PROD PJSM on laying dn wash string 12:15 - 13:30 1.25 CMPL TN PULD PROD Con't UD 3.5" wash string Printed: 4/24/2003 9:42:23 AM ') ) CoriClcoPhillips Alaska Opf3rations· SUmmary ,Report Legal Well Name: 1 C-17 4 Common Well Name: 1 C-17 4 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From- To Hours Code Sub Code 4/1/2003 13:30 - 14:00 0.50 CMPL TN PULD PROD 14:00 - 15:00 1.00 LOG RURD PROD 15:00 - 18:00 3.00 LOG ELOG PROD 18:00 - 18:30 0.50 LOG RURD PROD 18:30 - 23:00 4.50 DRILL PULD PROD 23:00 - 00:00 1.00 DRILL PULD PROD 4/2/2003 00:00 - 03:00 3.00 DRILL PULD CMPL TN 03:00 - 03:30 0.50 CMPL TN RURD CMPL TN 03:30 - 04:00 0.50 CMPL TN RURD CMPL TN 04:00 - 04: 15 0.25 CMPL TN SFTY CMPL TN 04:15 - 10:00 5.75 CMPL TN RUNT CMPL TN 10:00 - 11 :00 1.00 CMPL TN SOHO CMPL TN 11 :00 - 11 :30 0.50 CMPL TN CIRC CMPL TN 11 :30 - 12:00 0.50 CMPL TN PULD CMPL TN 12:00 - 13:00 1.00 CMPL TN SEOT CMPL TN 13:00 - 13:30 0.50 CMPL TN RURD CMPL TN 13:30 - 16:00 2.50 CMPL TN NUND CMPL TN 16:00 - 17:00 1.00 CMPL TN RURD CMPL TN 17:00 - 18:00 1.00 CMPL TN DEOT CMPL TN 18:00 - 19:30 1.50 CMPL TN CIRC CMPL TN 19:30 - 20:30 1.00 CMPL TN FRZP CMPL TN 20:30 - 22:00 1.50 CMPL TN RURD CMPL TN 22:00 - 22:30 0.50 CMPL TN RURD CMPL TN 22:30 - 00:00 1.50 CMPL TN RURD CMPL TN Page 7 of7 Start: 3/11/2003 Rig Release: Rig Number: Spud Date: 3/12/2003 End: Group: Description olOperations Clear all tools from rig floor - UD baker slick stick PJSM - R/U Schlumberger wire line Run USIT log wI Tractor - Log 7000' thru 6000' RID Schlumberger TIH wI HWDP & 40 stds 5" Dp from derrick - TOH UD all DP TIH wI 33 stds 5" DP out of derrick UD 33 stds 5" DP & 9 stds 5" HWDP + jars R/U & Pull wear bushing R/U to run 4.5" 12.6# L-80 NSCT Tbg completion PJSM on running completion - Review Tbg detail- Review hazards & pinch points. Run 4.5" 12.6# L-80 NSCT Tbg completion string per Tbg detail Space out - Install 2.16' pup jt 1 full joint below tbg hanger - No Go will be 3' above locator - Locator @ 7049' & No Go @ 7046' Circu tbg vol (107bbls) , 610 psi @ 9 bpm M/U Landing jt & Tbg hanger Land Tbg - RILDS - Test hanger 1000 psi 10 min "OK" UD Landing jt - R/U lub & Set BPV N/D BOPs - N/U Tree R/U lub - Pull BPV - Install TWC R/U and test 9.625" X 4.5" Ann. to 2500 psi and chart for 30 min - No psi loss after 30 min Con't pressure up from 2500 psi to 3110 psi - RP valve sheared - Pump psi = 1340 psi @ 3 bpm - Taking returns thru 4.5" Tbg Freeze protect ann & tbg wI 174 bbls diesel to 2504' MD (1920' TVD) RID Surface lines - Clean cellar area Set BPV - UD lubricator Install Hydr accuator valve on tree - Install all ported flanges and valve wI guages on tree - Secure well - Release Rig **** Note**** Rig Released @ Midnight 2400 hrs 4/2/03 Printed: 4/24/2003 9:42:23 AM ) ConocoPhillips Alaska, Inc. Pad 1C 174 slot #174 Kuparuk River Unit North Slope, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref OUr ref License MWD <0-12485'> svy6856 Date printed Date created Last revised 9-Apr-2003 ll-Mar-2003 31-Mar-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 30.832,w149 29 46.150 Slot Grid coordinates are N 5968779.438, E 562135.016 Slot local coordinates are 1458.06 S 1129.67 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ) ConocoPhillips Alaska, Inc. Pad 1C,174 Kuparuk River Unit, North Slope, Alaska Measured Inclin Depth Degrees 0.00 120.00 139.08 201. 09 293.29 383.76 472.12 562.90 654.55 742.43 833.55 924.27 1018.66 1107.48 1200.32 1292.21 1387.39 1437.27 1481.14 1572.61 1665.04 1758.43 1851.43 1943.75 2037.03 2129.59 2222.26 2315.08 2408.30 2501. 78 2593.84 2686.61 2780.32 2873.89 2967.40 3059.13 3153.69 3248.33 3339.61 3433.60 3524.38 3619.14 3712.17 3806.29 3897.98 3990.65 4084.89 4178.72 4269.56 4361.00 4.92 7.58 9.90 13.24 16.46 17.92 19.34 23.61 27.23 28.75 30.49 33.48 35.81 38.47 45.83 48.69 55.11 59.62 64.63 65.15 64.09 64.97 63.85 62.71 64.70 64.06 62.70 62.13 60.72 60.53 60.00 61.90 62.00 62.03 62.18 62.10 62.41 62.58 62.38 62.60 63.62 65.49 65.58 65.54 65.72 Azimuth Degrees 0.00 0.00 0.16 0.97 2.64 0.00 0.00 273.58 275.09 284.86 True Vert Depth 0.00 120.00 139.08 201. 09 293.24 383.51 471.33 561.05 650.83 735.76 822.81 908.77 996.59 1076.80 1158.78 1238.66 1319.38 1360.42 1395.39 1463.16 1525.88 1583.48 1633.62 1676.77 1716.36 1756.03 1795.89 1835.98 1877 . 89 1919.31 1959.12 2000.68 2044.08 2088.84 2134.71 2180.21 2226.13 2270.64 2313.48 2357.46 2399.88 2444.00 2486.96 2530.45 2572 . 80 2614.72 2655.21 2694.07 2731.66 2769.39 ) SURVEY LISTING Page 1 Your ref MWD <0-12485'> Last revised : 31-Mar-2003 R E C TAN G U L A R Dogleg Vert COO R DIN ATE S Deg/100ft Sect O.OON O.OON O.OON 0.05N 0.67N 2.51N 6.08N 12.09N 20.95N 32.16N 45.72N 60.70N 78.76N 99.23N 122.43N 146.05N 173.10N 188.86N 204.06N 240.87N 283.21N 329.45N 377 .78N 426.07N 473.55N 519.10N 563.42N 607.22N 651.58N 694.78N 735.82N 776.74N 819.40N 864.10N 910.34N 957.47N 1008.39N 1058.70N 1106.12N 1154.27N 1198.88N 1244.54N 1288.50N 1333.46N 1376.85N l418.49N 1460.84N 1504.51N 1545.93N 1586.54N O.OOE O.OOE 0.03W 0.64W 3.47W 9.13W 18.06W 30.46W 46.56W 66.10W 89.36W 114.17W 143.62W 175.76W 212.63W 251.42W 293.96W 317.52W 339.22W 388.27W 441 . 32W 498.39W 559.99W 625.74W 695.58W 765.71W 836.67W 908.01W 978.47W 1050.27W 1122.42W 1194.56W 1265.81W 1334.75W 1401.85W 1466.05W 1531.16W 1597.81W 1662.98W 1730.65W 1797.37W 1867.72W 1937.55W 2007.87W 2076.64W 2148.03W 2221.84W 2295.23W 2366.81W 2439.52W 0.00 -4105.45 0.00 -4105.45 0.84 -4105.44 1.31 -4105.26 1.84 -4104.04 2.54 -4100.99 3.04 -4095.55 2.67 -4086.96 3.66 -4074.78 3.67 -4059.56 1.61 -4041.21 1.64 -4021.15 4.53 -3997.07 4.22 -3970.03 2.12 -3939.30 1.96 -3907.74 3.22 -3872.00 4.92 -3851.44 6.25 -3831.86 8.26 -3785.17 3.20 -3732.21 6.88 -3674.56 5.07 -3613.88 5.76 -3552.33 2.18 -3490.66 1.17 -3430.82 1.95 -3371.99 1. 47 -3313.59 1.29 -3254.84 3.35 -3196.92 0.71 -3141.03 1.47 -3085.26 2.61 -3028.00 2.02 -2969.24 1.67 -2909.40 1.67 -2849.31 2.61 -2785.33 3.50 -2721.61 1.68 -2661.03 2.78 -2599.19 0.38 -2541.01 1.16 -2481.02 0.42 -2422.79 1.15 -2363.48 1.82 -2306.04 2.32 -2249.74 2.33 -2192.21 0.53 -2133.49 1.92 -2077.35 0.26 -2021.75 G RID COO R D S Easting Northing 562135.02 562135.02 562134.99 562134.38 562131.54 562125.86 562116.91 562104.46 562088.29 562068.67 562045.30 562020.37 561990.78 561958.47 561921.41 561882.44 561839.69 561816.00 561794.18 561744.84 561691.45 561634.01 561572.03 561505.90 561435.68 561365.18 561293.88 561222.19 561151.37 561079.24 561006.76 560934.30 560862.71 560793.41 560725.95 560661.37 560595.86 560528.81 560463.26 560395.20 560328.13 560257.42 560187.24 560116.56 560047.45 559975.73 559901.59 559827.85 559755.95 559682.91 5968779.44 5968779.44 5968779.44 5968779.49 5968780.08 5968781.87 5968785.37 5968791.28 5968800.01 5968811.05 5968824.43 5968839.20 5968857.02 5968877.23 5968900.12 5968923.42 5968950.13 5968965.70 5968980.71 5969017.12 5969059.02 5969104.80 5969152.62 5969200.36 5969247.28 5969292.25 5969335.99 5969379.20 5969422.98 5969465.59 5969506.04 5969546.37 5969588.44 5969632.58 5969678.26 5969724.87 5969775.25 5969825.01 5969871.90 5969919.49 5969963.56 5970008.64 5970052.02 5970096.40 5970139.23 5970180.29 5970222.03 5970265.09 5970305.93 5970345.95 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #174 and TVD from RKB (Doyon 141) (87.20 Ft above mean sea level). Bottom hole distance is 10103.33 on azimuth 327.87 degrees from wellhead. Vertical section is from N 3266.99 W 4180.07 on azimuth 347.31 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 289.69 293.18 297.88 299.56 300.07 300.41 301. 78 301.29 303.55 300.87 301.78 303.08 304.44 305.53 308.07 309.09 308.95 307.33 305.30 303.13 302.87 301.12 301.98 302.40 299.70 299.56 299.57 302.25 303.68 305.46 307.12 308.92 305.17 306.91 303.96 303.58 302.39 301. 99 303.19 301.32 299.20 300.48 301. 02 299.10 299.27 ) ConocoPhillips Alaska, Inc. Pad 1C,174 Kuparuk River Unit,North Slope, Alaska Measured Inclin Depth Degrees 4454.88 4548.04 4640.85 4733.69 4826.30 4919.45 5010.26 5105.25 5199.37 5292.36 5383.47 5476.98 5570.18 5663.07 5756.18 5849.95 5942.91 6035.30 6128.06 6220.66 6265.00 6314.40 6406.42 6500.40 6591.77 6683.94 6777.51 6870.47 6962.43 7056.15 7129.67 7174.00 7251. 46 7344.38 7437.86 7525.58 7624.20 7714.01 7809.35 7900.32 7992.84 8086.73 8178.24 8273.12 8366.97 8458.91 8551.80 8644.42 8737.42 8830.46 65.42 65.63 65.42 65.51 65.58 65.75 65.68 65.55 65.59 66.16 66.82 67.49 65.85 65.71 65.49 65.58 65.61 65.55 66.01 66.63 67.40 68.31 70.48 73.41 75.85 78.12 80.18 81.45 82.29 82.17 82.13 82.05 81.91 82.10 82.10 82.17 83.71 84.32 85.89 86.82 88.87 91.54 93.82 93.94 92.90 92.81 92.81 92.59 92.59 92.84 Azimuth True Vert Degrees Depth 302.47 299.32 296.39 299.72 301.60 307.28 315.37 318.15 317.74 314.16 310.30 306.24 302.77 304.15 304.53 303.48 302.67 304.35 307.41 311 . 03 313.65 316.53 320.78 326.80 331.92 338.53 342.12 341. 76 343.76 345.12 345.79 346.14 346.76 346.37 346.41 346.77 346.66 347.62 346.82 348.19 349.02 349.03 349.06 347.89 347.74 346.43 346.80 346.07 348.52 348.60 2808.22 2846.83 2885.28 2923.84 2962.19 3000.60 3038.00 3077.22 3116.15 3154.16 3190.52 3226.84 3263.76 3301.86 3340.33 3379.16 3417.57 3455.77 3493.83 3531.03 3548.35 3566.98 3599.37 3628.52 3652.75 3673.53 3691.15 3705.98 3718.99 3731.66 3741.70 3747.80 3758.61 3771.53 3784.38 3796.39 3808.51 3817.87 3826.01 3831. 79 3835.27 3834.93 3830.65 3824.23 3818.64 3814.06 3809.50 3805.14 3800.94 3796.53 ) SURVEY LISTING Page 2 Your ref MWD <0-12485'> Last revised : 31-Mar-2003 R E C TAN G U L A R Dogleg Vert COO R DIN ATE S Deg/100ft Sect 1630.39N 1673.92N 1713.38N 1753.10N 1796.08N 1844.06N 1898.66N 1961. 67N 2025.30N 2086.28N 2142.41N 2195.77N 2244.25N 2290.95N 2338.78N 2386.52N 2432.71N 2479.16N 2528.73N 2582.35N 2609.84N 2642.24N 2706.90N 2778.97N 2854.75N 2936.24N 3022.75N 3110.00N 3196.94N 3286.39N 3356.89N 3399.49N 3474.05N 3563.55N 3653.55N 3738.07N 3833.32N 3920.40N 4013.04N 4101.67N 4192.29N 4284.46N 4374.20N 4466.95N 4558.52N 4648.02N 4738.28N 4828.21N 4918.84N 5009.93N 2512.88W 2585.63W 2660.30W 2734.82W 2807.33W 2877.28W 2939.38W 2998.64W 3056.04W 3115.04W 3176.89W 3244.53W 3315.03W 3385.70W 3455.72W 3526.47W 3597.41W 3667.55W 3736.08W 3801. 76W 3831.92W 3864.22W 3921.08W 3973.80W 4018.66W 4056.24W 4087.17W 4115.62W 4142.60W 4167.50W 4185.79W 4196.44W 4214.41W 4235.79W 4257.58W 4277.73W 4300.22W 4320.10W 4341.12W 4360.76W 4379.02W 4396.90W 4414.27W 4433.18W 4452.95W 4473.47W 4494.95W 4516.65W 4537.08W 4555.52W 3.12 3.09 2.88 3.26 1. 85 -1962.86 -1904.42 -1849.52 -1794.40 -1736.54 G RID Easting 559609.21 559536.12 559461.13 559386.30 559313.45 559243.11 559180.58 559120.82 559062.90 559003.42 558941.12 558873.05 558802.17 558731.12 558660.73 558589.60 558518.30 558447.79 558378.86 558312.76 558282.37 558249.82 558192.43 558139.14 558093.67 558055.42 558023.80 557994.65 557966.97 557941.33 557922.47 557911.48 557892.90 557870.80 557848.28 557827.44 557804.18 557783.60 557761. 84 557741. 48 557722.48 557703.86 557685.76 557666.10 557645.58 557624.33 557602.12 557579.70 557558.53 557539.36 COO R D S Northing 5970389.19 5970432.12 5970470.97 5970510.08 5970552.47 5970599.87 5970653.95 5970716.48 5970779.63 5970840.13 5970895.75 5970948.55 5970996.45 5971042.57 5971089.83 5971136.98 5971182.60 5971228.46 5971277 . 47 5971330.55 5971357.79 5971389.92 5971454.11 5971525.74 5971601.15 5971682.32 5971768.58 5971855.58 5971942.29 5972031.53 5972101.87 5972144.37 5972218.78 5972308.10 5972397.90 5972482.25 5972577 . 31 5972664.21 5972756.67 5972845.13 5972935.59 5973027.60 5973117.19 5973209.77 5973301.17 5973390.49 5973480.57 5973570.31 5973660.76 5973751.69 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #174 and TVD from RKB (Doyon 141) (87.20 Ft above mean sea level). Bottom hole distance is 10103.33 on azimuth 327.87 degrees from wellhead. Vertical section is from N 3266.99 W 4180.07 on azimuth 347.31 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 5.56 8.12 2.67 0.40 3.57 -1674.36 -1607.46 -1532.96 -1458.28 -1385.83 3.95 4.06 3.84 1. 36 0.44 -1317.48 -1250.57 -1187.79 -1126.70 -1064.66 1. 02 0.79 1. 66 3.05 3.64 -1002.55 -941.89 -881.18 -817.76 -751.03 5.71 5.71 4.92 6.84 6.03 -717.58 -678.87 -603.31 -521.41 -437.63 7.41 4.36 1. 42 2.34 1.44 -349.87 -258.68 -167.32 -76.57 16.17 0.90 0.80 0.81 0.46 0.04 88.96 132.86 209.55 301.56 394.14 0.41 1.57 1.26 1.85 1. 82 481.03 578.89 668.21 763.20 853.98 2.39 2.84 2.49 1.24 1.12 946.41 1040.25 1131.61 1226.25 1319.93 1. 43 0.40 0.82 2.63 0.28 1411.75 1504.52 1597.03 1689.93 1782.84 ., ConocoPhillips Alaska, Inc. SURVEY LISTING Page 3 Pad lC,174 Your ref MWD <0-12485'> Kuparuk River Unit,North Slope, Alaska Last revised : 31-Mar-2003 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COO R D S Depth Degrees Degrees Depth COORD I N ATE S Deg/100ft Sect Easting Northing 8922.86 92.71 347.91 3792.06 5100.29N 4574.30W 0.76 1875.12 557519.84 5973841.88 9014 .10 92.74 347.68 3787.72 5189.36N 4593.57W 0.25 1966.25 557499.85 5973930.79 9107.08 91.18 346.99 3784.54 5280.02N 4613.94W 1. 83 2059.17 557478.74 5974021.27 9200.01 88.81 346.86 3784.55 5370.54N 4634.9SW 2.55 2152.09 557456.99 5974111.61 9292.72 87.89 347.25 3787.22 5460.85N 4655.72W 1. 08 2244.76 557435.50 5974201.74 9390.06 88.44 346.58 3790.33 5555.62N 4677.75W 0.89 2342.05 557412.70 5974296.31 9479.66 84.01 349.03 3796.23 5642.97N 4696.64W 5.65 2431.42 557393.11 5974383.51 9571.55 85.03 346.25 3805.01 5732.31N 4716.21W 3.21 2522.88 557372.81 5974472.67 9664.54 84.97 345.89 3813.11 5822.23N 4738.51W 0.39 2615.50 557349.78 5974562.39 9758.88 84.44 345.86 3821.82 5913.32N 4761. 44W 0.56 2709.40 557326.12 5974653.29 9850.97 84.48 347.98 3830.71 6002.60N 4782.18W 2.29 2801. 06 557304.65 5974742.39 9943.81 84.54 346.99 3839.59 6092.82N 4802.21W 1. 06 2893.47 557283.90 5974832.43 10039.02 84.48 348.56 3848.70 6185.44N 4822.27W 1. 64 2988.24 557263.08 5974924.88 10131.98 84.35 347.73 3857.75 6275.98N 4841.28W 0.90 3080.74 557243.34 5975015.26 10180.45 85.65 348.78 3861.97 6323.26N 4851.11W 3.44 3129.02 557233.13 5975062.44 10224.20 86.57 350.53 3864.94 6366.19N 4858.95W 4.51 3172 . 63 557224.94 5975105.31 10272.15 88.02 351.73 3867.20 6413.51N 4866.33W 3.92 3220.42 557217.17 5975152.57 10318.14 88.92 349.43 3868.43 6458.86N 4873.8SW 5.37 3266.31 557209.28 5975197.85 10366.00 90.01 349.39 3868.88 6505.91N 4882.65W 2.28 3314.14 557200.11 5975244.81 10410.58 90.68 349.59 3868.61 6549.74N 4890.78W 1.57 3358.69 557191.62 5975288.57 10456.84 91.88 349.58 3867.58 6595.22N 4899.14W 2.59 3404.90 557182.89 5975333.99 10503.56 92.65 350.41 3865.73 6641.20N 4907.25W 2.42 3451.53 557174.41 5975379.89 10595.92 93.20 349.69 3861.02 6732.05N 4923.19W 0.98 3543.66 557157.73 5975470.60 10689.00 93.08 348.91 3855.92 6823.37N 4940.45W 0.85 3636.55 557139.74 5975561.77 10782.51 93.05 349.59 3850.92 6915.11N 4957.8SW 0.73 3729.87 557121.58 5975653.35 10874.92 93.11 348.52 3845.95 7005.70N 4975.38W 1.16 3822.10 557103.32 5975743.79 10965.52 93.94 350.96 3840.38 7094.68N 4991.49W 2.84 3912.44 557086.49 5975832.63 11058.87 95.24 352.08 3832.91 7186.71N 5005.21W 1. 84 4005.24 557072.03 5975924.53 11151.39 95.33 349.03 3824.39 7277.58N 5020.33W 3.28 4097.20 557056.17 5976015.27 11243.69 95.20 347.27 3815.92 7367.52N 5039.20W 1. 90 4189.10 557036.57 5976105.05 11336.57 94.71 346.72 3807.90 7457.68N 5060.02W 0.79 4281.63 557015.02 5976195.03 11384.99 93.02 344.52 3804.63 7504.47N 5072.02W 5.72 4329.92 557002.64 5976241.71 11429.52 92.86 344.84 3802.35 7547.37N 5083.77W 0.80 4374.34 556990.54 5976284.50 11477.38 91.79 345.67 3800.41 7593.61N 5095.94W 2.83 4422.13 556978.00 5976330.64 11522.30 90.59 344.67 3799.47 7637.02N 5107.44W 3.48 4467.01 556966.15 5976373.96 11572 .02 89.00 344.66 3799.65 7684.97N 5120.59W 3.20 4516.67 556952.62 5976421.79 11617.17 87.89 344.22 3800.88 7728.45N 5132.69W 2.64 4561.75 556940.16 5976465.17 11666.32 86.72 344.08 3803.19 7775.68N 5146.10W 2.40 4610.77 556926.37 5976512.28 11711.03 86.11 344.71 3805.98 7818.66N 5158.10W 1. 96 4655.33 556914.02 5976555.15 11759.42 85.83 344.83 3809.38 7865.23N 5170.78W 0.63 4703.55 556900.96 5976601.62 11803.94 84.66 343.93 3813.07 7907.96N 5182.73W 3.31 4747.86 556888.67 5976644.25 11852.20 84.04 345.33 3817.83 7954.26N 5195.4SW 3.16 4795.83 556875.56 5976690.44 11895.89 82.84 343.68 3822.82 7996.09N 5207.05W 4.65 4839.18 556863.63 5976732.17 11945.33 82.60 344.16 3829.08 8043.21N 5220.64W 1.08 4888.14 556849.67 5976779.17 11987.52 82.78 344.76 3834.45 8083.53N 5231.85W 1. 47 4929.93 556838.13 5976819.39 12076.90 82.65 344.15 3845.78 8168.94N 5255.61W 0.69 5018.48 556813.68 5976904.60 12167.89 82.72 343.09 3857.37 8255.53N 5281. OSW 1.16 5108.54 556787.53 5976990.97 12258.79 82.59 342.46 3868.99 8341.64N 5307.7SW 0.70 5198.41 556760.13 5977076.85 12348.88 82.59 343.67 3880.61 8427.10N 5333.78W 1.33 5287.51 556733.42 5977162.09 12438.55 82.32 342.86 3892.38 8512.23N 5359.37W 0.94 5376.18 556707.13 5977247.00 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #174 and TVD from RKB (Doyon 141) (87.20 Ft above mean sea level). Bottom hole distance is 10103.33 on azimuth 327.87 degrees from wellhead. Vertical section is from N 3266.99 W 4180.07 on azimuth 347.31 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) ) ConocoPhillips Alaska, Inc. Pad lC,174 Kuparuk River Unit,North Slope, Alaska SURVEY LISTING Page 4 Your ref MWD <0-12485'> Last revised : 31-Mar-2003 Measured Inclin Depth Degrees Azimuth Degrees True Vert Depth R E C TAN G U L A R Dogleg Vert COO R DIN ATE S Deg/100ft Sect G RID Easting COO R D S Northing 12485.00 82.32 342.86 3898.59 8556.22N 5372.94W 0.00 5422.07 556693.21 5977290.87 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #174 and TVD from RKB (Doyon 141) (87.20 Ft above mean sea level). Bottom hole distance is 10103.33 on azimuth 327.87 degrees from wellhead. Vertical section is from N 3266.99 W 4180.07 on azimuth 347.31 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) ) ConocoPhillips Alaska, Inc. Pad 1C,174 Kuparuk River Unit,North Slope, Alaska SURVEY LISTING Page 5 Your ref MWD <0-12485'> Last revised : 31-Mar-2003 Casing positions in string 'A' ---------------------- --------------------- Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 O.OON O.OOE 7168.00 3746.97 3393.72N 4195.02W 9 5/8 CSG Targets associated with this wellpath ------------------------------------- ---------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- WS V8 B-TOE RVSD 07 556736.000,5977115.000,-2.000 WS V8 HEEL TGT R'LOC 3847.20 3733.20 8379.98N 3266.99N 5331.58W 4180.07W 10-Apr-2002 9-Jan-2003 Conoc~Phillips ) ConocoPhillips Alaska, Inc.,slot #174 Pad 1 C, Kuparuk River Unit,North Slope, Alaska f) 03 - Od -::¡- SURVEY Lib I I~G Page 1 Well bore: 174 Well path: MWD <0-12485'> Date Printed: 9-Feb-2004 r&i. BAKER HUGHES INTEQ Well bore Nªm~ 174 ...-,-..--,--- "','-, -,,"',-'---1-,--.-' , -,--, -, '--,','- .----,---------..-.-.---. _ , , ", LªstR.~v¡sed_ 9-Feb~2004 ...n___._._._._..'_·_'_'__ -_.._--------~-- -lfi~~~~20Ó3 _.~,-_.,-_..---_.._-..--,,--,,_.. ....... .-- .. -.-...-.--...-,--.......---..--.-.-.--.--.... ..--.-.--...- ...,-.--,..." ..... ._.,__....._ ._....____.,._.__.."...".__...._,__,." _. .._.........__,,__. .,,'.. '-".'-'_."_0- _'n .,. - .. __"._.. _._" .~_. .__"...~___..__..__._"'".,_._.__._._..________. bOo' ,_._ .___~_...._ .__.__..."......_._......... .___....... ......... ,,'.. .- - --,_.._.-,.. '--"""-'''-'''-'-'''-"-'-'-'~'-''.- Well .----.-.-..------- Name 174 '-'--------------.-..------..--....-...-.---[.------.'---..-------...,-,--,.,..--------..---------..-.--,-,---....".,...-'--',·-"----"-----..--'1'-----'----'-------..--------------...---.-,..,---,---,----,-..---..,--------,----, Government ID Last Revised 19-Jan-2003 Slot Name slot #174 , "" , -"n'-'"'r~~~~~;~~~~~" --r~~~1-~;~~~" '-IL;t~~~~-19' 30.8323 Lonqitude W149 29 46.1502 North 1458.06S East 1129.67E .Inª~ª,Uª1iQn,."__,,.", Field Name Kuparuk River Unit I E~~ii~q 487;~4.~~~rN~rthinq 5948985_"82~JC~t~ ~~s~e;R~~m:MERICA~ DATUM 192;~atuJNorth Aliqnment True 6reated'Bv Comments RECE:.I,1lEl), FEB 20 2004 Ala0lŒ Ùil ~I Gas Gons. Gomnns,slon Anchor~ge All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 87.2ft above mean sea level) Vertical Section is from O.OON O_OOE on azimuth 347.31 degrees Bottom hole distance is 10111.91 Feet on azimuth 327_85 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~~)'}\\~ Conoc;Pt,illips ) ConocoPhillips AlasKa, Inc.,slot #174 Pad 1 C, Kuparuk River Unit,North Slope, Alaska SURVEY UOJ JNG Page 2 Well bore: 174 Well path: MWD <0-12485'> Date Printed: 9-Feb-2004 r'¡. BAKER HUGHES INTEQ We II path (G ri (U_ Re po 11__..,__.___,__.._.._..,__________,_.]._.__.______.._.._.,... __...__._,_._.,_._____..__,..___._.__._.._...,_...__..._._.,__._,_.,...,._..____.__...__,...._______...._....._.....___,. ..~~[~~~"',...,__ ..I,~~~~~=],_.,~i[~:=]....,' ,,_ "~~.~,~f~]....,"""'" _~~~~~~~~_"._"" ,'.,..'" ,.E~_~~[~]".__.__. '. ",.~~~~~Qft],...,.,._ .'. ~:~~~~~J.ftl",., Easting Northing 0,00 9.00. ",.,Q.Oo. .,o.,Qo.,_O,OQN 9,9.91= 0.00 ,9.90 5132J,3.~.Q2.. . _5913,ª7.7~,44 120.00 0.00 0.00 120.00 O.OON O.OOE 0.00 0.00 562135.02 5968779.44 n9,..Oß OJ6 .2Z~.5ß 139.9ß,Q,QQN O.Q~W. ,0,134 0,,01 q621~A.,~9. ..~9ºa7L9A4. __.2Q"t..Q!L ,,9.-9.7. .,1.. 2Iq,.09_ .2Q1,o.9 ._-º,Qþ~. ._QJ>4V\1, .." .J,:3..1..._,.... 9,J9., 562.134.38 ,,_Q.9.º-6n.~.49 293.29 2.64 284.86 293.24 0.67N 3.47W 1.84 1.41 562131.55 5968780.08 3133.76 4"!:I 2 28~,99383.51 2,.£>JI\I 9J3W2.,54. _ 4,4!5 ..£j62J2q,86!5~68Z81.87 472.12 7.58 293.18 471.33 6.08N 18.06W 3.04 9.90 562116.91 5968785.37 562.90 9.90 297.88 561.05 12.09N 30.46W 2.67 18.48 562104.46 5968791.27 654.55 13.24 299.56 650.83 20.95N 46.56W 3.66 30.67 562088.29 5968800.00 742.43 16.46 300.07 735.76 32.16N 66.09W 3.67 45.89 562068.66 5968811.04 8J~.ºþ.._._.____1ZJ1.2....___Jºº.".4..L____a_22'_a.l._,___._ 45. 721L__,._._ 89 .36W ,.._j-'_I3J.._...____~,21._.,_...._.__Þ.§,2Q4Q2JL____,._,.... 5968824.4L_.__. 924.27 19.34 301.78 908.77 60.70N 114.17W 1.64 84.30 562020.36 5968839.18 19.113.13.13. 23,131 , ,.. 301.29., .!:I913,.£j9 .7ßJJ>N. . 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J-ª,ß_,.ªºN.,_ ., ,."__3J],,þ.Zw.,. 4.92 ....294.QO.._ºº1..8.t9..9L...__ .,þ.9Jt8.9..E>þ',§5 1481.14 38.47 305.53_ 1395..3,9 2Q4.,06N3.39.22W 6,Z.!5 273.,!5,9 !56J79.4.t5., §9.6ß9aQ.66 _.1572.61 45.83 308.07 1463.16 240.87N 388.27W 8.26 320.28 561744.80 5969017.06 1665.04 48.69 309.09 , 1525.88 28.3.21N,. 441,32W 3,20 . 373.24 .5.61.691..415969Q9a.96 1758.43 55.11 308.95 1583.48 329.45N 498.39W 6.88 430.89 561633.96 5969104.72 1851.43 59.62 307.33 1633.62 377.78N 559.99W 5.07 491.57 561571.98 5969152.53 1943.75 64.63 305.30 1676.77 426.07N 625.74W 5.76 553.12 561505.83 5969200.27 2037.03 65.15 303.13 1716.36 473.56N 695.58W 2.18 614.79 561435.61 5969247.17 ....._2:1.,29,.59... .,_,.6.4.1>.9.. .___,.3.Q2,-ªZ..'_n ___..JL5.6--'º4, _.n, .J:>.J9--'lQN___. .._.. _..Ì.!?9-=-l.1YY......__...__._J-'JI.... ...._!?Z4J'-ª...m_.'...__5J?J;3ºlL11___,_._,_596ª-29.2J.~_ 2222.26 64.97 301.12 1795.89 563.42N 836.67W 1.95 733.46 561293.80 5969335.86 ,2;3J,9,.Qß,.. ..6~,J~§,._ . ,3,Qt.98. _..18..:3_£),,98.., . ___.__607,2Zr~L """"....,ª_º-8...QJ"l'lu_. t,~Z_._._. __. 79L8..£:L.. _...._5§J24.Z,.lQ_.__...Þ.9º9~?JtQ9, ,,24-º8....:3()_ 62.71 .:3Q,Z,ÆQ, .. _.J-ªZI,,8..9. . _.._..6.þ..Lþ.a..r~L_..n.'..,_..9I/:}A7W.,. . .., ,J,.2!:1_. __.8..QQJLL . __ _..._.._£)9..1..15.1.,28...,.._ ...,..__J~9.º_9.A2_~.ª,3....__ , ..2~Qt1.ª_ , ,_94~0_.", nn.29jLZ.Q..... .,. ..19J9....:3.L."e,94_,.IßN.... .___..1º.9Q,.2ZW_._ ._n_~,35___,_.._..._9..QJL5.3.._ __9_61 Q7ª-,JJ, . 5969.4º9A~_,.., . _.. ,?Q.9.3JH: .9,4.,Qº.,2Im.,_QZ ,.'" ._J,9_59,..12__ .l.3.º,..8.~N_. . .n..,...1122A,2W. ..O]J.,_.., .. ..!:I§4AZ_... . ._5.9JQ.Q§J3.þ..._.__,_._...__ 5.9.!lli5.Q§,ßlt.. .. _. .2-ºªº_,§J, ,._ _ J12.10__ . __ ._..4.9.9,-~'L_ _~2º-Qo...º8....___ ......I76. 7-º1..L_.._'.n..1Jß_4.5.ß'Y______ _.1.:.1:L ,..__._ ,_lQZ£t2_º__ ,9ºQ9_:3_4J_9.._ . .9ª6J~§4.E5-,~.Q__....__ .,' 2Z8..Q.32__º-2,J,:3. 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", .,.þ.º-º?9~_,.2jL... . ..___!5'ª-º-ª6,32,39 2967.40 60.53 305.46 2134.71 910.35N 1401.84W 1.67 1196.06 560725.82 5969678.06 __._:3,Q.!5_9.. n..._, .J3,Q._32 .:3Q7.-..12. .._2J79,9.9,_. . , 9,þ.Lp.9N._.. _, 1..46.13,.1 4.VY... ,..., .1...!59 _ 1_256.25 . ..5_6_Q..I3.E>JJA .__._,._5.9º-9..724..7.4___ 3153.69 62.23 308.92 2225.43 1008.64N 1531.46W 2.62 1320.43 560595.41 5969775.27 3248.33 62.32 305.17 2269.47 1059.10N 1598.31W 3.51 1384.34 560528.15 5969825.16 3339.61 I 62.36 306.91 2311.85 1106.66N 1663.68W 1.69 1445.10 560462.40 5969872.18 3433.60 I 62.51 303.96 2355.35 1154.96N 1731.55W 2.79 I 1507.13 560394.13 5969919.91 3.Q2.4,38.. ,.c º-2.4~_ ..30.3,98 2397.31 .1J_9.ª.2tN ,.179.ßA7W... , _, 0.38_. !. 19€?5A..f3_ .5.€?Q3.Z§..8p...5.9J>J:lJ!64J.o.. 3619.14 62.74 302.39 2440.95 1245.50N 1869.03W 1.16 I 1625.66 560255.92 5970009.30 3712.17 i 62.91 301.99 2483.43 1289.59N: 1939.07W 0.42_,. 1684.06 .9§Q1-ª5.~5.:3. _!_5.97_0J>"~2ßQ._ -3.àQ~'.29=!·'§2,i1 3..Q.á.J9 ..~i~2i4_4~ 'i3j¿:6_~N=I_' -ici6i6:iiV-.. 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BAKER HUGHES INTEQ -----,..-.---.---,-.-,-----...--.---.,.-.....--,.----...'~----_._.__._._---_._-_._._~.__._-----,,_.,._--_..- Northing All data is in Feet unless otherwise stated Coordinates are from Slot MDts are from Rig and TVD's are from Rig ( Doyon #141 87.2ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 347.31 degrees Bottom hole distance is 10111.91 Feet on azimuth 327.85 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ;>,9Z0433.·.ß,5 5970472.80 !5.JJ.ZQ!51L99 , 5QIºQP4.~9 5970602.00 5970656.22 5970718.91 5970782.22 5970842.85 5970898.61 Þ,9709.5t.92 5970999.53 ~,9I,:Lº4q,U !597JOSJ.3.,14. !?9ZJJ4Q,4 1. ., .5971J8.ß.J4 ..',. ___Þ~J.23..2.JJ.. 591.1.2a1..2.þ, , 597J ;334..45 5971393.96 597149a,27 5971530.03 5971605.55 5971686.82 5971773.16 ~9Z18§0..,24 5971947.02 Q972º.:39,32 q9Z2JOe,71 ., ..."", ,--º.9Z.222~J$L.".",..., . ._____f>972:312..:9ª_____ n .., _,n.5972402..za_.. , ,59724.aZ. 1.3 ", ,..,..R9.72.5ª.2.J.a '.. 5972669.08 9972Zßt,5~"" 5972849.99 5972940.45 5973032.46 5973122.04 I .5,973~HJ¡"2 ,.. , I 5973306.02 I _ !5_~I3.:39f>._:34 ...Þ91348..Q.41 .q~1.3..ÞZ~,15~ __, .5973665.59 5973796.52 ,997.3846.7:1 5973.9.3,5.61 , 5974026.09 5974116.42 Conoc~illips ) ConocoPhillips AlaSKa, Inc.,slot #174 Pad 1 C, Kuparuk River Unit,North Slope, Alaska SURVEY LI.. .1NG Page 4 Well bore: 174 Wellpath: MWD <0-124851> Date Printed: 9-Feb-2004 ,&¡. BAKER HUGHES INTEQ Well path (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Easting Northing _..,.._.,.._,_._,...,_., ..__.__.._.._. .. ....,."...__......,... .. ...,..__.__....m..__. , ,.___....,_,___..._.".Jº~gl1.QQftL. ... ... .~~.G.tlQnrftL_, ,."......m'n_..__..._ ._.. . . ,'. ..___._._.. .9.~~.~..n_ ß7ß,9.,~4Z,~9...~Z9.4~,.ªZ_. .9~§º,~~HJ'J.,. .m4ºº,4~IHW ,....1.,.0.8.... ,º~.!?L~~.,..!5.5.z~47..9_3"...!5ßZ44.o§.!55 9390.06 88.44 346.58 3767.99 5561.21N 4684.86W 0.89 6454.51 557404.73 5974301.12 __1~~:~~ _::~~.. . . ~:i~: -::~~~~~.. ... ;1~~::'~--1i¿U;0 .i:ii-n _ -:-~:~1~ ··_~~g}t~~=__I·. __~miii:;~ n 9664.54 84.97 345.89 3790.77 5827.82N 4745.63W 0,39 6727.96 557341.76 5974567.19 . 97!5ß..88 {H,.14... 345.86 3.Z99Aa ...9,9.18..9tN ,4Lº8.,Q9\1Y. ..Q.Q6,. .l3e.~JJ3.7. . _997~tß"Q9. 9974£:3.98.0.9 9850.97 84.48 347.98 3808.37 6008.19N 4789.30W 2.29 6913.52 557296.61 5974747.18 9943.81 84.54 346.99 3817.25 6098.41N 4809.32W 1.06 7005.93 557275.84 5974837.22 10039.02 84.48 348.56 3826.36 6191.03N 4829.39W 1.64 7100.70 557255.01 5974929.66 10131.98 84.35 347.73 3835.41 6281.57N 4848.40W 0.90 7193.21 557235.25 5975020.04 1.QJ.ßQAR ,_. _ªÞJ>Q...:3.4ßJ8., .:3a~9,13~ n ,.. 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",..,., ..Q51J.º'º',2.6___,.,.. . , ,5_9X_!?~ß..4,..I3.º ..1.o5!:}.5.9293.2Q 349.69 3838..64. 67~7,64N 4ß~Q,:31\IV 0.,98 7.13.56..13 !557J49.5ß5ß.I9.4ZqJ7 10689.00 93.08 348.91 3833.54 6828.96N 4947.56W 0.85 7749.01 557131.57 5975566.54 107J3~.51 .93..05 34ß.!593828.Q~ 139~Q..ZQN ,. 49.f:3.4,.ß.eW .0]3 78.4.4.,3~h !597J13.39 !59.79135.ßJ.2 10874.92 93.11 348.52 3823.57 7011.30N 4982.50W 1.16 7934.56 557095.13 5975748.56 10965.52 93.94 350.96 3818.00 7100.27N 4998.60W 2.84 8024.90 557078.28 5975837.39 11058.87 95.24 352.08 3810.53 7192.30N 5012.33W 1.84 8117.70 557063.80 5975929.29 11151.39 95.33 349.03 3802.01 7283.17N 5027.44W 3.28 8209.67 557047.94 5976020.02 -.112.4~ºª-_..u....9.º~2º___,_..;3.4L2L._ ..._ 37~,3_.Q4__..._ . _1~L3..1..1N_,___._!5Q.4º".:31...\¡~'-_. _,__. 1.90 8301 .57___,,_. 557028.32.______59761 09.Jill. 11336.57 94.71 346.72 3785.51 7463.27N 5067.14W 0.79 8394.10 557006.75 5976199.77 ....J..t3.ª4.,.~~L n....'., .ß~......Q2,.......,.___.~~H'-.5..4._.. ._...~Z§_z..f_!L_. _ _Z!5J.-º~.QZN_...._...._9.º.?J~.J.4Y\t.. .. ....9,,12.... , .... ._..,..ª-442..,3,ª...,.._.._.,,§_ºº9~4,;3.Z..__,.... .,. ,..,_"!;?9Zº'2,,4ºÆ~_. .._..l14.29,,_!?2.,_ _ ".. 92'-.8-º_"....3.4.4...M. ,_..._:3.7.I~,,~Z...,' _ .,]º-5.,2J@·',t__ , .. ,9.º9-º,..a.~W. , , ....', .ºß..Q_.._..,..,_..,Jt4.11§,ªL..__._.Q!5.f:3~ª2."_2Z.._... ,_., ..._ .,.9_91ß28.º..29_.._,...,... 114.?],,:3JL_,....9.L.?JL,.,. ......3~tQ,º7.... ,_3?.1ß...Q3.._. __I!5Jl9.:.4,Q.N,..,.. 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Q~...4ºW_._ _. .__"4A.o,,..,_...,.. ....ß.I.2.:i,.24..._.. _ ... .5.!5º.9..1LßZ__ _, ,.,...,.,...9.~Zº-5Jlì,,9.6___.. . 11711.03 86.11 344.71 3783.60 7824.20N 5165.40W 1.96 8767.79 556905.51 5976559.84 -m~~~ --::~:~EH~ -i~tE I tirm~m~m'~~~ ·t;~ -!:~:~~'æ:!~1~~!ti:~~~ 11895.89 82.84 343.68 3800.44 I 8001.63N 5214.36W 4.65 8951.64 556855.10 5976736.84 11945.33 82.60 344.16 3806.70 i 8048.75N 5227.94W 1.08 9000.60 556841.12 5976783.84 _.__lH~ªL,5_2_.___.ª~....L~....r··.3_4~Zº' _.__~8.12~_o.L -I -~~~~:~~-- i -..~~~;~~;-~-.... .... u~:·~~_.._-l-·~~~~:~~..---···-{~~~i~~~~-· ...~_.-- -~~i~:~:~~~'-"I ~~~l~~ L ~~~LL ~~~~~ ... l~~:~~ ¡ ª2_6JJJ1!!i_ó.2ªª,~~__ JJß _!__9mºº__ _ _~ Õ§67IªJ1.L+- __59769-ª.5cE;3 __.1..nq8.,Iß L _8...2......59..__ ~ . ..3.42..4.6 ,', ._,.3_8.4§J5j_, .......a.3ßI1~J'L+._~31~,0_e.W.. . 0.7º,___.!_,,~:ltº"-8,L._ _. _§'~ºZ51..,Q.9__..!....__º9.?ZOß1.51 _.12~4.8.,aª~~] __ _8..2..99.._.L ~.3~3.!3.7. ...aa.Qll.Z:3_ ·ß.4~2..6.4J'L...L.Q.:34LQª-W. __t..33___ ~._.~;3-9...!Lge.. .._5_Q.13.IZ4..a2... .,.~..,__....5.9..7.IleJLl4...._.~ 12438.55 I 82.32 I 342.86 3870.00 I 8517.77N : 5366.68W 0.94 : 9488.63 556698.52: 5977251.65 i =.i2iá~j)O,.:~·=ßi32~m~..:·~~4·~Ü¡e'---_-=~ª?9~2.1. .. !,... .8!5131]§N ,,,T" -=~iio~2~W~ __.0. QO,,_...-==~9.9i4-.Q:3_~===_=~~fi8A:59-=}__=:..,~.=~~ZI2~~~~£--..] ------,'---~.- All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 87.2ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 347.31 degrees Bottom hole distance is 10111.91 Feet on azimuth 327.85 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ..' ConocoPhillips ) ConocoPhillips AlasKa, Inc.,slot #174 Pad 1C, Kuparuk River Unit,North Slope, Alaska SURVEY LI"", )NG Page 5 Wellbore: 174 Wellpath: MWD <0-12485'> Date Printed: 9-Feb-2004 rGi. BAKER HUGHES INTEQ Comments _,r~LDrftl !IYJ2HtL____._,__.N_Q[tblftL_=:=J EasUftL__~-=_-=--1 Comm~I1L____.__'__.____________'__..,.._,.______'_____.._. _.___..____....._.. ._..._ .._____..."""__...____. ,.',,'. ,,_J24ß,q.QQ.. "",. ,3ßZß..2.L ",8qG1 ~ie~_Þ,~aO,2ÞV'JPrQi~çteq t,O..BitQepttl_,__ .."..... ...,.-........--"."...-"...,.,.,...-. ._.,____._~...__.._.._._~_,_..____.__,_.,,_,,___.'"____..._._........_._._.____.._..._._____._,____,.,___._._______..__.__,__..________._._._._.~.__,.__.,__~________._____..._____,.___.._"..._."..........._.____. .. _.__..__...____,....__...._._......·"..._..._.__P....___~_._..,.._._..__,.~.,..,_._,."_,,_..'.___.,,.._..__,,____,._w.n Hole Sections Diameter Start Start Start I Start End End End Start nnl MDrftl TVDrftl Northfftl Eastrftl MDrftl TVDrftl Northrftl Eastrftl "-J~...~';~--'----7'17~:~~ --- "-""372~~~~ -'m-340~·~~~-...---4io~.'~~~ ,'.... -1~~:~.~~-- -, '--;~~~:~;------~~~~:'~'~~ '-~~~~~~-~~ ~ ~: Well bore Casinas Name Top MDrftl Top TVDrftl O.OQ O.pO ,7123,0(, Top Top Shoe Shoe Shoe Shoe Northrftl Eastrftl MDrftl TVDrftl Northrttl Eastrftl ,O,QQ O.OON_u ,___Q,--QQ~u__., 120.0C . .._J2Q,0_0 O.OpN , ,_Q,P_Q_l;t?4__, , . ____Q.QQ m_ ___Q,QON ...... ", QJtQI; ,.", __lJº-ß,.QC ... . __31.2.~..J3Ç ____ ___~~ª~2.9..h ~_A2.º2.,l.3...'ð J,H______......._,.__._"__,._.._...______.__.___, ", .,_~.7Ja..a,;... u _~3QQ,º2N _~ 191 ,';.7"" 12~_aQ,Qç , __3a.ZG,2,1",.. J~QºJ.7.9~...5_~ªQ'--2_!5y.,tZ4,_..__ Wellbore tG~'_ÇºJ1d],J~tQ[ JLQ!Jf'_Ç_ª~ng ,. QJ!211 $IQ!t~_clJIne.L, All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 87.2ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 347.31 degrees Bottom hole distance is 10111.91 Feet on azimuth 327.85 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Schlumberger NO. 2765 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 05/05/03 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Color 35-21 ~o..1~031 SBHP SURVEY 04/18/03 1 1 B-08A I q 7-/~ I INJECTION PROFILE 04/17/03 1 35-09 ~:jj/"J-5 INJECTION PROFILE 04/07/03 1 3S-10 d ... -3;;) PRODUCTION PROFILE 04/08/03 1 1G-13 j,-NO PRODUCTION PROFILE 04/09/03 1 3S-21 (')3 31 SCMT 04/18/03 1 1C-174~'3--~Î 23113 US IT 04/01/03 1 1G-03 I 8-/49 INJECTION PROFILE 04/24/03 1 1C-135 ~ ð/- d::Jn PRESSITEMP SURVEY 04/23/03 1 ~/!: S'GNEé...-: r-~ It Ü1;p<-~ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk CD ---' -- RECEIVED MAY 082003 AJaska ot: & Gas Cons. Commi5!ion A.nchomge ) Transmittal Form INTEQ To: AOGCC 333 West ih Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 1C-174 '\ Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) I 1 LDWG lister summary 1 blueline - MPR Measured Depth Log 1 blueline - MPR TVD Log LAC Job#: 426350 Sent By: Glen Horel Received By: :) r&l. BAKER HUGHES Anchorage GEOScience Center Date: Apr 25, 2003 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 RECEIVED APR 28 2003 AJalka Oí~ & Gas Cons. CQmm~~n Anchorege (;)03-0;;7 ¡I-¡/(P r.·C::~:~:~::;:~~~~·~·1: . ;'..1":':,,' i:-r~ ~ :~, ,~.~ ~,.;:, i..... :~-=-'-~::ÿ;-';;.~;-_.~_'::~: :~:'!'!.,...,""RI,...,."',\ !:~:.::., E:;y~"...- -,..... ¡----_.._j~~!~,':_,------------- L·~~;¿~,~~,..:~·h;R'~~~.·~?~~:~~;~~~_r1~ I ~~I : "'I'J', , ~, ~~.~.....~I.,.._ ..~_i ,_.,I/I.'~ ,..II~,,!".!~· f:-:~·~':·,'T~~::~~ ..,-.,.--...'- : -' ,~ "... ~ - - - - ~-- . fL.-I?£/.. Subject: Change Surface Location on lC-190-- Date: Wed, 12 Mar 2003 16:08:42 -0900 From: "Steven M Shultz" <Steven.M.Shultz@conocophillips.com> To: winton_aubert@admin.state.AK.US Change Surface Location on 1 C-190 ) Winton, Thanks for the help. 1 C - J..9.9- 111- 1458' FNL and 1129' FWL sec. 12, T11N, R10E, UM Z-~" ~ ,- O'L7 \ ) 4~"'- Co (" V€>C /-"(1:1'--_ vt C lrlJ· p.. / 'tt- ')~, tC""J e. [} {-. ~,lL.ll 1 é - L 7 t-/. CM'- - ~'y ~J M~ U-.- ~ µ//-f. s1",,!!-. 75/ / ~,12/tO"-D '~, ïtJ b /~'~~VI~ ~ ¡:;-.=ìJ/Æc:--;:J ~ ' ~ " I Ú L ' Û I ~ ') j !Æ ~!Æ~~~!Æ I o FRANK H. MURKOWSK/, GOVERNOR AI¡ASIiA. OILAlWD GAS CONSERVATION COMMISSION Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage AK. 99510 333 w. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Unit 1C-174 ConocoPhillips Alaska, In~. ~. Permit No: 203-027 1'/').1& j I Z-f1 iJ..I4!.. Surface Location: ~ FNL,~' FWL, Sec. 12, T11N, R10E, UM Bottomhole Location: 3639' FNL, 1083' FWL, Sec. 35, T12N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals' required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness' any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this 7t!- day of February, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section 6. Property Designation ADL 25649 & 25638 ALK 467 & 463 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) Kuparuk River Unit Statewide 8. Well number, Number 1C-174 /' #59-52-180 9. Approximate spud date; Amount February 15, 2003 $200,000 14. Number of acres in property 11' Proposed depth (MD and TVD) 2560 12293' MD 13847' TVD 17. Anticipated pressure (se10 AAC 25.035 (e)(2» Maximum surface 1436 psig At total depth (TVD) 1821 psig Setting Depth ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ,/ PERMIT TO DRILL 20 AAC 25.005 1b. Type of well. / Exploratory U Stratigraphic Test Service 0 Development Gas 0 Single Zone 5. Datum elevation (OF or KB) RKB = 87 feet AMSL U o 1 a. Type of work: Drill ~ Redrill 0 Re-entry DDeepen 0 2. Name of Operator ConocoPhillips Alaska, 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface ~it'JL,~FWL,Sec.12, T11N, R10E, UM At t~r~p,oductitt rn~~al .~~(\ 3532' FNL, 2246' FWL, Sec. 2, T11 N, R1OE, UM At total depth . 3639' FNL, 1083' FWL, Sec. 35, T12N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well ! 1083' @ TD feet 1C-1356' @ 1200' 16. To be completed for deviated wells Kickoff depth: 300 MD 18. Casing program size feet Maximum hole angle 93° Top Bottom TVD 120' 3732' 3847' Hole Casing Weight 24" 16" 62.5# 12.25" 9.625" 40# 8.5" 5.5" 15.5# Specifications Grade Coupling H-40 Weld L-80 BTCM L-80 SLHT Length 120' 7037' ~ 5~S'" MD 59' 59' ~ "" ~1( "-'SA: TVD 59' 59' 3166' MD 120' 7037' 12293' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Plugs (measured) Effective Depth: feet feet Junk (measured) measured true vertical Casing Conductor Surface o Size Cemented Measured depth Length Perforation depth: measured true vertical [tJ6A- Z-/ (p 10 "3 Development Oil U Multiple Zone D 10. Field and Pool Kuparuk River Field / West Sak Oil Pool Quantity of Cement (include stage data) 332 sx AS 1 1029 sx AS III L & 258 sx Class G Slotted liner - no cement True Vertical depth r~~~ 20. Attachments Filing fee 0 Property Plat D BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0Time vs depth plot Qefraction analysis DSeabed report 020 AAC 25.050 requirements 0 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Steve Shultz 263-4620 Signed ~ \. ~ Title: Kuparuk Drilling Team Leader Date '2... (<-;(.::> ~ . R. Thomas· ) PrAnRrArl hv ShRmn AIlf:/m-nrRkA ~ee cover letter for other requirements Yes ßJ No R] Yes D No T€~\-· -go PE Commission Use Only ~~3~eð z.7 I AP~~_um~~? - Z.3 / SJ <) I Approval date¡" 1 J?J Conditions of approval Samples required DYes,g¡ No Mud log required Hydrogen sulfide measures D Yes ~ No Directional survey required Required working pressure for BOPE D2M; 0 3M; D 5M; D 10M; D Other: /Vl t: L I c.......\.. t ~ UcI.J¿ ~ tr: ~ "~~ ,-,\...£ t'-< d . ÖRIGINAl SIGNED BY M I . Rill D by order of Approved by Commissioner the commission Form 10-401 Rev. 12/1/85· )r,!~~r~rA , tí i l;¡ J ¡J,L\~ Date f-c:t "SSOO f.1; (ì I ~J'\//J. J I/~ \ Submit in triplicate I ) ConocóP'hillips Well Plan Summary Horizontal Locations¡4S-S' uz.'t q ~~t- Location at Sulface jJ-5æ' FNL, -H~ FWL, See 12, TllN, Rl0E, UM NGS Coordinates RKB Elevation Northings: 5,968,735.1 Eastings: 562,201.6 Pad Elevation Location at Top of Productive Interval (West Sak "D" Sand) NGS Coordinates Northings: 5,971,952 Eastings: 557,945 3532' FNL, 2246' FWL, See 2, TllN, Rl0E, UM Measured Depth/ RKB: Total Vertical Depth/ RKB: Total Vertical Depth/55: I 3639' FNL, 1083' FWL, Sec 35, T12N, Rl0E, UM Measured Depth/ RKB: Total Vertical Depth/ RKB: Total Vertical Depth/55: Location at Total Depth NGS Coordinates Northings: 5,977,115 Eastings: 556,736 Formation Markers and Directional Waypoints Description Doyon 141 RKB 20" Conductor Base Permafrost Top K-15 Top Ugnu C Top Ugnu B Top Ugnu A K-13 Shale Top West Sak D 9-5/8" Casing Point C-l B-1 B-2 C-2 C-3 B-3 B-4 C-4 C-5 B-5 TD - 7" Liner Point Steve Shultz Measured Depth (RKB feet) 28 120 2116 3283 5310 5904 6010 6496 7037 7037 7333 7488 8221 8462 9662 9950 10669 10973 11965 12133 12294 True Vertical Depth (RKB feet) 28 120 1743 2282 3166 3412 3455 3622 3733 3733 3769 3788 3799 3785 3795 3816 3819 3800 3806 3827 3847 True Vertical Depth (SS feet) 31 1656 2195 3079 3325 3368 3535 3646 3646 3682 3701 3712 3698 3708 3729 3732 3713 3719 3740 3760 ISSUED, Printed 198{2~3 ~3~42 PM o hi , Li i ¡ :J I~ _ ) Drill and Complete Procedure West Sak Well #lC-174 BID Sand Undulating Injector AFC 87.3' AMSL 59.2' AMSL / 7,037 3,727 3,640 12,294 3,849 3,762 Page 1 of 5 '\ '~.. l ConocoPhillips ) Drill and Complete Procedure West Sak Well #1C-174 BID Sand Undulating Injector AFC Casing/Tubing Program Hole 1 / Casing Csg/Tbg / Top Btm Size OD Wt/Ft Grade Conn. Length MD/TVD MD/TVD 12-1/4" OH 9-5/8" 40# L-80 BTCM 7,009' Su rface 7,037'/ 3,733' 8-1/2" OH 5-1/2" 15.5# L-80 Hydril 511 ~ .~/~' 12,294' / 3,847' D/B sand S'SS& · c"q ~ 1 ; WlZA- 9-5/8" 4-1/2" 12.6# L-80 IBTM 6,900' Surface 6,928' / 3,715' Casing Tubular Dimensions and Strengths OD Wt Conn. Cplg OD ID Drift Collapse Burst Tensile Yield (in) (ppf) Grade Type (inches) (inches) (inches) (psi) (psi) (kips) 9-5/8 40 L-80 BTCM 10.625 8.835 8.679 3,090 5,750 947 5-1/2" 15.5 L-80 Hydril 511 Flush 4.860 4.825 4,990 7,000 259 4-1/2 12.6 L-80 IBTM 5.200 3.958 3.833 7,500 7,700 208 Logging/Formation Evaluation Program Rotary Steerable, MWD Directional, LWD (GR/RES) 12-1/4" Open Hole Section 8-112" Open Hole (D/B Sand) Cased Hole Rotary Steerable MWD (Directional, Pressure while Drilling, At Bit Inclination) LWD ( GR 1 RES) 9-5/8" bond log to be run once 5 1/2" liner is set Surface Hole Mud Program Gel Spud Mud System Density (ppg) Funnel Viscosity (seconds) Yield POint(cP) Plastic Viscosity (lb/100 sf) 10 second Gel Strength (lb/100 sf) 10 minute Gel Strength (lb/100 sf) pH API Altrate(cc) Solids (%) Steve S h u Itz Spud to 500' Initial Value Final Value 8.5 8.5-8.8 J 250-300 250-300 40-60 40-60 7 -15 7 -20 20-30 20-30 25-60 25-60 8-9 8-9 8-15 8-15 3-8 3-8 ISSUED, Printed 1/28/2003 3:42 PM C ,." ~,f), f· J ," ¡Ill ì ¡ 'tj l~ . Page 2 of 5 y) ConocoPhillips ) Drill and Complete Procedure West Sak Well #1C-174 B / D Sand Undulating Injector AFC LSND Density (ppg) Funnel Viscosity (seconds) Yield POint(cP) Plastic Viscosity (lb/100 SF) 10 second Gel Strength (lb/100 SF) API Filtrate(cc) Lateral Mud Program LSND Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (lb/100 sf) Tau 0 ChloT/äes pH API filtrate **HTHP f/1trate MBT Solids (%) ** HTHP to be run at 80° F 500' to 12-1/4" TO Initial Value Base of Final Value Permafrost Value 9.0 9.4 10.4 / 60-70 45-55 45-55 30-34 20-25 20-25 8-13 11-21 15-23 1 0-1 5 1 0-15 1 0-15 <10 <6 <6 D sand lateral Initial Value 9.0 45-60 18-25 Final Valu! 9.0 45-60 18-25 8-14 8-14 4-7 4-7 14-16K 14-16K 8.5-9.0 8.5-9.0 <6 <6 <10 <10 <12.5 <12.5 4-7 4-7 Cementing Program Casing Hole Category Size/Depth Volume Type of Cement Properties Surface / 9-5/8" 1 7.037' 70 bbls CW100 Pre-flush Density 8.4 ppg Production 50 bbls Mudpush XL Density 10.2 ppg Top of Tail at 6400' 785 bbls / Lead Slurry (AS Lite) Density 10.7 ppg / MD 1 3593' TVD (1029 sacks) Yield 4.28 ft3 Isk Top of West Sak D / at 6976' MD 1 3725' 54 bbls ../ Tail Slurry Density 15.80 ppg TVD (258 sacks) Class "G" Cement Yield 1.17 ft3 1 sk Steve Shultz ISSUED, Printed 1/'?,QP,~; (~1P,f1, A hi ¡ f OJ ,~ ~ \; ¡',i_i ~ J \f. II ':! .']-- Page 3 of 5 ) ConocóPhillips Drill and Complete Procedure West Sak Well #lC-174 BID Sand Undulating Injector AFC Well Objectives and Justification / lC-174 is proposed as a 5316' (vertical section) undulating D/B injector (HUI) east of lC-178 multilateral producer. The proposed well path drops about 40 feet structurally from south to north, and no faults are indentified along the path. T~ total length of the well has been set to place the toe to offset the planned TD of lC-178, and is about 625 feet from a bounding fault to the north. Review of oil-water contacts indicate the B Sand could be in the OWC transition at the toe where the target depth is only 15 feet above the mapped OWC (3775 ss). Since an OWC shallower than expected could cause reconsideration of the length or location of lC-178, the lC-174 should be drilled first. Reservoir Pressure and Well Control The expected reservoir pressures in this area are some what in question due to the closest well, (lC-lll) having been on injection with no appreciable off take. After modeling the well for pressure predicted migration, it is believe that the majority of the water injected migrated to the easy away from the area of where lC-174 is to be drilled, and that the estimated pOle pressure is ±1600 psi or a 8.6 MWE. The lates~ pressure recorded for lC-l11 was 1821 psi which equates to a 9.8 ppg pore pressure. The plan is to drill into the West Sak Sand with a lOA ppg mud as a precaution, then once / the 12 V4" surface hole is at TD, the 9 5/8" casing will be set and the mud weight will be dropped back to a 9.0 ppg while ~, ., in undulating lateral. The maximum surface pressure that would be seen with a gas column in the hole would be c¿ psi assuming a .1 psi/ft gradient for gas. Close Approach and Anti-Collision Risks and Mitiqation There are no close approach issues. Waste Drillinq Fluids Disposal Incidental fluids generated from drilling operations may be hauled to the nearest permitted disposal well or may be pumped down the surface / production casing annulus of a permitted, existing well on Drill Site-1D. Possible Class II disposal well is lR-18. Cement rinsate is not to be injected down any of these dedicated disposal wells but should be recycled or held for an open annulus. Well #lC-22 has permitted for annular injection. All waste fluids hauled from lC-174 must be properly documented and manifested. Only permitted fluids may be disposed of in this annulus, once permitted, and any fluids disposed of should be properly /' recorded and reported to Sharon Allsup-Drake, the Anchorage Drilling Aide. No more than 32,000 barrels should be disposed of in any permitted annulus without approval from Drilling Team Leader or Drilling Engineer. For further information on annular disposal procedures and reporting see Annular Disposal Procedures and Annular Disposal Reportinq Guidelines on the Drilling Web page. Steve Shultz ISSUED, Printed 1/28/2003 3:42 PM Page 4 of 5 J '11' !i~ .1 ~~, ,'A I " ~ 1l,1 ì j iJ f"' '.~ ) ConocJPhillips ) Drill and Complete Procedure West Sak Well #1C-174 BID Sand Undulating Injector AFC Summary Procedure / 1. Move in/ Rig up Doyon #141 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. Steve Shultz /' Install diverter / BOPE and function test Spud and directionally drill 12 V4" hole to the 9 5/8" casing point at 7,037'MD/3733'TVD as per directional plan. Run MWD, LWD tools as required for directional monitoring and data gathering. /' Run and cement the 9 5/8",40#, L-80, BTC Mod Casing to surface. Displace cement with mud and perform stage job if necessary. =:,'""o,.;}ollar to be run at ±1,OOO', remove 16" diverter line, install blind flange'}ftivate and test B,OPts ~(annUlar preventer to 2500 psi), Notify AOGCC 24 hours prior to test, PU 8 112" bit and RIH on directional assembly, once at top of float collar, test casing to 2500 psi for 30 / minutes, drill out to within 10 feet of 9 5/8" casing shoe, change over to new drilling fluid, drill 5 feet of formation, stop and check for flow, drill an additional 15 feet of formation. Perform an FIT to i2.0 ppg MWE and record results. - Change over to clean LSND drilling fluid and directionally drill an 8 V2" hole to 12,294'MD/3847'TVD as per directional program. Condition hole for running the 5 V2" slotted liner, change over to viscosified brine / ~_... G:, OJ ~ ., I \'-L~ ,,/ RU and run 5 V2", 17#, L-80, Hydril 511 slotted liner, set liner/hanger packer at ±6,-98tTMD/3725'TVD / RU and run CBL from liner top to 500' above the Ugnu. -- RU and RIH with 4 112", 12.6#, L-80, IBTM production tubing with seals Space out and land tubing with seal assembly into PBR on hanger Install back pressure valve and ND BOPE. Install production tree a~test same, pull BPV, test annulus to 2500 psi, continue to pressure up to 3000 psi to shear out GLM Freeze protect the well with diesel down the annulus, circulating through the GLM Install back pressure valve and release Doyon #141 / ISSUED, Printed 1/2&1t2Cj ¡~~ ~~. J f1 "i I ~ ~ ~ . " :' ,~ ' L .. . I ~ j J :,/}' ~ , Page 5 of 5 ) ) lC-174 Drilling Hazards Summary (Details of of these risks follow on next page) 12 1/4" Open Holel 9 5/8" Casing Hazard Risk Level Mitigations Broach of Conductor Low Monitor cellar while drilling surface hole, conductor set @ 120' which is 40 feet deeper then the 80 foot standard of the past Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Dril treat Running Sands and Gravels Low Maintain planned mud parameters, weighted mud, viscous sweeps Abnormal Reservoir Low Diverter drills, increased mud weight, flow Pressure checks Lost Circulation Low Reduced pump rates, rheology, LCM Swabbing Moderate Trip speeds, proper hole fill, pumping out / 8 1/2" Open Holel 5 ~" Slotted Liner Hazard Abnormal Pressure Risk Level Low Stuck Pipe Lost Circulation Hole Swabbing on Trips Low Low Low Mitigation Stripping drills, shut-in drills, increased mud weight Good hole cleaning, backreaming after TD Reduced pump rates, rheology, LCM Trip speeds, proper hole fill, pumping out J ~¡!~G'!' If!~ f ~ L GIll CJ Ii ff ; II'~, , g i:lJ$~~",~ a ::t:J r~.->""~ ~J --..- ~~¡~ ~'.~-~ .....'" ,~ r-- .. 1 C-17 4 116" Conductor , @ 1201 ~NiPPle @ 5001 ~ ConocoPhillips o 5 1/2" X 1" GLM @ 2,0001 MO 4 1/2",12.6, L-80, NSCT ~ Hole Size: 12 1/4" Plan to drill 12 1/4" hole and 8 1/2" hole with 5" drill pipe. -' Hole Size: 8 1/2" ~ --:::- ---=- :::- --------- --- -.:::::::::- ---- -- --.::::- -- -- ~ ~ \ --------- ~ ~ 95/8",47#, L-80, Buttress 5 1/2", 15.5#, L-80, SLHT +/-7,03T MO Slotted Liner ~ 37331 TVO ~ -- -- ==------- --- ---~ -- -~ ~ 12,294IMO· ~'847TVO --- -- ---- ------ ..:::::::- - ------= --- --- ) ) ConocoPhillips Alaska, Inc. Pad lC 174 slot #174 Kuparuk River Uni t North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License lC-174 Vers#1.c prop5335 Date printed Date created Last revised 20-Jan-2003 12-Nov-2002 20-Jan-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 30.832,w149 29 46.150 slot Grid coordinates are N 5968779.438, E 562135.016 Slot local coordinates are 1458.06 S 1129.67 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Or"; :! lr-~ ,q ',0/ ~ I , t",: ti Ù "j .~' .;' rJ , , ~ ~ \i'i.~ ,I r~ '~'Jm O f::!~ (' u [&,' ^L n .~ \d11 ¡ V /~ 4180.07W 9-Jan-2003 5331. 58W 10-Apr-2002 3266.99N 8379.98N WS V8 HEEL TGT R' LOC 3733.00 WS V8 B-TOE RVSD 07 556736.000,5977115.000,-2.000 3847,00 - -- -- - - - - - - - - -- - - -- - - --- - ---- - --- - - - - --- - --- - - - - - - - - - - - - - ----- -- - - - -- - - --- -- -- - - - - - -- -- - - - - - - -- - - - - - - - - - - -- Revised Rectangular Coordinates T.V.D. Geographic Location Target name - - - ---- --------- - - - - - --- - - -- - - --- -- -- ------------------------------------- Targets associated with this we11path 4180.07W 9 5/8 CSG 3266.99N O.OOE 7037.18 3733.00 o .OON 0.00 0.00 200.00 200.00 o .OON O.OOE KOP 600.00 598.70 10.44N 25.85W Curve 4/100 1967.24 1674.26 416.47N 666.14W EOC 2116.11 1743.00 490.32N 775.62W Base Permafrost 2666.20 1997.00 763.16N 1180.13W Top T-3 3283.41 2282.00 1069.31N 1634.01W Top K-15 4188.67 2700.00 1518.32N 2299.70W Build 4/100 4264.67 2733.29 1556.52N 2356.34W EOC 4908.81 3000.00 1884.40N 2842.43W Turn 4/100 4915.82 3002.90 1887.95N 2847. nw EOC 5309.67 3166.00 2086.81N 3146.00W Top Ugnu C 5903.71 3412.00 2386.76N 3595.89W Top Ugnu B 5906.99 3413 .36 2388.42N 3598.38W Beg Final B1d/Trn 6009.76 3455.00 2443.45N 3674.50W Top Ugnu A 6496.44 3622.00 2780.93N 3979.13W K13 6976.41 3725.00 3208.49N 4165.73W Top West Sak D 7037.16 3733.00 3266.97N 4180.07W 9 5/8" Csg - EOC 7037.18 3733.00 3266.99N 4180.07W WS V8 HEEL TGT R' LOCD 09JAN03 7332.58 3769.00 3553.02N 4244.49W C-1 7488.48 3788.00 3703.98N 4278.49W B-1 7579.59 3799.10 3792.20N 4298.35W Begin Build 7993.19 3812.29 4194.94N 4389.06W EOB 8221.40 3799.00 4417.20N 4439.11W B-2 Inverted(BaseC) 8461. 65 3785.00 4651.18N 4491.81W C-2 Inverted(BaseD) 8901.97 3759.35 5080.01N 4588.38W Drop 2.5/100 9202.77 3761.55 5373.24N 4654.42W EOD 9661.70 3795.00 5819.77N 4754.99W C-3 9949.80 3816.00 6100.08N 4818.12W B-3 10148.56 3830.49 6293.46N 4861.67W Begin Build 10458.96 3832,11 6596.04N 4929.82W EOB 10669.00 3819.00 6800.55N 4975.87W B-4 Inverted(BaseC) 10973.30 3800,00 7096.84N 5042.60W C-4 Inverted(BaseD) 11387 .03 3774.16 7499.67N 5133.32W Begin Drop 11816.36 3787.53 7917,70N 5227.47W EOD 11964.70 3806.00 8061.29N 5259.81W C-5 12133.30 3827.00 8224.49N 5296.56w B-5 12293.92 3847,00 8379.96N 5331.58W TD - Csg pt 12293.94 3847.00 8379.98N 5331.58W WS V8 B-TOE RVSD 07 JAN 03 Casing positions in string 'A' - - --- -- - - ---------------- -- --- - - ----- - - -- -- --- ------- -- ----- Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- ----------------------------------------------------------------------------------------------------------- Comment Rectangular Coords. TVD MD -- - --- - - -- --- ------- -- - -- - - - ---- -------- Comments in we11path PROPOSAL LISTING Page 4 Your ref 1C-174 Vers#l.c Last revised : 20-Jan-2003 ConocoPhi11ips Alaska, Inc. Pad 1C, 174 Kuparuk River Unit, North Slope, Alaska ) ') ) '\ Baker Hughes INTEQ , Anticollision Report Company: ConocoPhillips Alaska, Inc. Date: 1/16/2003 Time: 16:37:49 Page: 1 Field: Kuparuk River Unit Reference Site: Pad 1 C Co-ordinate(NE) Reference: Well: 174,True North Reference Well: 174 Vertical (TVD) Reference: Wellhead(87') 87.0 ReferenceWellpat~C-174 Vers#1.c Db: Oracle NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Plan: 1C-174 Vers#1.c & NOT PLANNED :>~OGI Interpolation MethodsllD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 0.00 to 12293.94 ft Scan Method: Trav Cylinder North Maximum Radiu~OOOO.OO ft Error Surface: Ellipse Plan: 1C-174 Vers#1.c Date Composed: 11/11/2002 Version: 92 Principal: Yes Tied-to: From Surface Summary OffSet Wellþàtb..............-............-............-...-...........> Reference Offset Ctr"'CfF N()"'G() Allowåble Well WelJpath MD MD DistanceArea Deviation Warn~ ft ft ft ft ft Pad 1 C 01 1 C-01 V2 290.07 300.00 351.06 4.73 346.32 Pass: Major Risk Pad 1 C 02 1 C-02 VO 293.53 300.00 235.43 4.79 230.64 Pass: Major Risk Pad 1 C 03 1 C-03 VO 297.23 300.00 130.66 4.86 125.80 Pass: Major Risk Pad 1 C 04 1 C-04 VO 700.00 700.00 76.54 12.57 63.98 Pass: Major Risk Pad 1 C 05 1 C-05 VO 1019.01 1000.00 62.06 20.26 41.81 Pass: Major Risk Pad 1 C 06 1 C-06 VO 1161.10 1100.00 120.98 24.63 97.59 Pass: Major Risk Pad 1 C 07 1 C-07 VO 1770.23 1600.00 94.69 49.59 46.16 Pass: Major Risk Pad 1 C 08 1 C-08 VO 1638.09 1500.00 56.41 41.70 14.94 Pass: Major Risk Pad 1 C 09 1 C-09 VO 1657.08 1500.00 234.26 51.43 182.84 Pass: Major Risk Pad 1 C 10 1C-10 VO 1169.51 1100.00 360.58 25.19 335.54 Pass: Major Risk Pad 1 C 102 1C-102 V4 5244.44 5100.00 265.84 285.54 16.10 Pass: Minor Risk Pad 1 C 102 1C-102L 1 V3 2993.14 2700.00 98.51 101.91 38.52 Pass: Minor Risk Pad 1 C 104 1C-104 VO 2188.12 1800.00 338.04 86.98 280.39 Pass: Major Risk Pad 1 C 104 1C-104L1 V1 2188.12 1800.00 338.04 86.98 280.39 Pass: Major Risk Pad 1 C 104 1C-104PB1 VO 2188.12 1800.00 338.04 86.98 280.39 Pass: Major Risk Pad 1 C 109 1C-109 VO 1820.84 1700.00 65.72 60.69 11.44 Pass: Major Risk Pad 1 C 109 1C-109L 1 VO 1820.84 1700.00 65.72 60.69 11 .44 Pass: Major Risk Pad 1 C 111 1 C-111 VO 6100.00 6000.00 397.94 402.29 16.48 Pass: Major Risk Pad 1 C 11 1C-11 VO 1794.53 1500.00 296.86 56.72 248.74 Pass: Major Risk Pad 1 C 113 1C-113 VO Plan: 1C-113 1.00 1.00 384.86 No Offset Errors Pad 1 C 115 1C-115 VO Plan: 1C-115 1.00 1.00 363.67 No Offset Errors Pad 1 C 117 1 C-117 VO 1069.35 1000.00 312.77 23.25 290.62 Pass: Major Risk Pad 1 C 119 1 C-119 VO 525.97 500.00 323.82 9.50 314.51 Pass: Major Risk Pad 1 C 121 1C-121 VO 629.51 600.00 308.09 11.88 296.50 Pass: Major Risk Pad 1 C 12 1C-12 VO 1461.80 1400.00 142.54 40.82 102.41 Pass: Major Risk Pad 1 C 123 1C-123 VO 624.93 600.00 296.77 11.89 285.15 Pass: Major Risk Pad 1 C 125 1C-125 VO 410.68 400.00 285.26 7.33 278.00 Pass: Major Risk Pad 1 C 127 1C-127VO 304.49 300.00 275.58 5.21 270.39 Pass: Major Risk Pad 1 C 131 1C-131 VO 199.99 200.00 266.20 3.07 263.14 Pass: Major Risk Pad 1 C 13 1 C-13 VO 1243.61 1200.00 55.97 27.11 28.86 Pass: Major Risk Pad 1 C 133 1C-133 VO 602.73 600.00 258.93 10.45 248.55 Pass: Major Risk Pad 1 C 135 1C-135 VO 199.98 200.00 271.71 3.06 268.66 Pass: Major Risk Pad 1 C 14 1C-14 VO 394.87 400.00 110.88 7.17 103.72 Pass: Major Risk Pad 1 C 15 1C-15 VO 294.34 300.00 209.41 4.99 204.44 Pass: Major Risk Pad 1 C 16 1C-16 VO 1006.44 1000.00 82.75 24.07 59.30 Pass: Major Risk Pad 1 C 17 1C-17 VO 2763.61 2400.00 196.77 137.94 101.09 Pass: Major Risk Pad 1 C 172 1C-172 Vers#1.b VO Pia 601.93 600.00 25.20 11.65 13.56 Pass: Major Risk Pad 1 C 178 1C-178 BLat Vers# 2 V 297.30 300.00 81.66 5.37 76.29 Pass: Major Risk Pad 1 C 178 1C-178 D Lat Vers# 2 V 297.30 300.00 81.66 5.37 76.29 Pass: Major Risk Pad 1 C 18 1C-18 VO 908.31 900.00 70.37 17.37 53.05 Pass: Major Risk Pad 1 C 190 1C-190Vers#8 V2 Plan: 200.00 200.00 320.02 3.40 316.63 Pass: Major Risk Pad 1 C 19 1 C-D(19) Vers#O.a VO P 291.25 300.00 281.58 5.26 276.32 Pass: Major Risk Pad 1 C 22 1 C-22 VO Plan: 1 C-22 V 200.00 200.00 240.11 3.40 236.72 Pass: Major Risk Pad 1 C 23 1 C-23A V2 292.99 300.00 252.36 4.93 247.44 Pass: Major Risk Pad 1 C 23 1 C-23PB 1 VO 292.99 300.00 252.36 4.93 247.44 Pass: Major Risk Pad 1 C 24 1 C-24 VO 200.00 200.00 264.42 3.78 260.64 Pass: Major Risk Pad 1 C 25 1 C-25 VO 291.35 300.00 307.00 4.75 302.25 Pass: Major Risk Pad 1 C 26 1 C-26 V2 290.87 300.00 322.88 4.78 318.10 Pass: Major Risk Pad 1 C 27 1 C-27 V1 199.99 200.00 338.27 3.00 335.27 Pass: Major Risk Pad 1 C b (PB) 1 C-PB Vers#O.a VO Plan 294.78 300.00 161.51 5.32 156.20 Pass: Major Risk Pad 1 C c (B) 1 C-B Vers#1 a VO Plan: 296.03 300.00 121.42 5.34 116.08 Pass: Major Risk Pad 1 C f (IB) 1 C-I B Vers#1 . a VO Plan 293.56 300.00 201.61 5.29 196.33 Pass: Major Risk Pad 1 C WS-1 WS1 VO 9363.45 3800.00 385.70 267.47 118.08 Pass: Major Risk Pad 1 C WS-24 WS-24 VO Out of range O_r~?~)!f!l ' . nJ t ¡" ~; ,f /\J .ifJ ' ~,' f 1 .U ~1 Ii ~1 d., _~~ ) ) ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 1 Pad 1C,174 Your ref 1C-174 Vers#l.c Kuparuk River Unit,North Slope, Alaska Last revised : 20-Jan-2003 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 100.00 0.00 292.00 100.00 0.00 N 0.00 E 0.00 0.00 200.00 0.00 292.00 200.00 0.00 N 0.00 E 0.00 0.00 KOP 300.00 2.00 292.00 299.98 0.65 N 1. 62 W 2.00 0.99 400.00 4.00 292.00 399.84 2.61 N 6.47 W 2.00 3.97 500.00 6.00 292.00 499.45 5.88 N 14.55 W 2.00 8.93 600.00 8.00 292.00 598.70 10.44 N 25.85 W 2.00 15.87 Curve 4/100 700.00 11.93 296.37 697.17 17.65 N 41. 57 W 4.00 26.35 800.00 15.90 298.59 794.22 28.80 N 62.86 W 4.00 41.90 900.00 19.87 299.94 889.37 43.84 N 89.63, W 4.00 62.46 1000.00 23.86 300.86 982.16 62.71 N 121.73 W 4.00 87.92 1100.00 27.85 301.52 1072 .13 85.30 N 159.02 W 4.00 118.15 1200.00 31.84 302.03 1158.85 111.52 N 201.31 W 4.00 153.02 1300.00 35.83 302.44 1241.89 141. 22 N 248.39 W 4.00 192.34 1400.00 39.83 302.78 1320.86 174.28 N 300.04 W 4.00 235.93 1500.00 43.83 303.06 1395.36 210.52 N 356.01 W 4.00 283.58 1600.00 47.82 303.30 1465.03 249.77 N 416.02 W 4.00 335.05 1700.00 51.82 303.52 1529.54 291.83 N 479.78 W 4.00 390.10 1800.00 55.81 303.71 1588.57 336.51 N 546.98 W 4.00 448.45 1900.00 59.81 303.89 1641.82 383.59 N 617.29 W 4.00 509.82 1967.24 62.50 304.00 1674.26 416.47 N 666.14 W 4.00 552.64 EOC 2000.00 62.50 304.00 1689.39 432.72 N 690.23 W 0.00 573.78 2116.11 62.50 304.00 1743.00 490.32 N 775.62 W 0.00 648.72 Base Permafrost 2500.00 62.50 304.00 1920.26 680.73 N 1057.92 W 0.00 896.50 2666.20 62.50 304.00 1997.00 763.16 N 1180.13 W 0.00 1003.77 Top T-3 3000.00 62.50 304.00 2151.13 928.73 N 1425.60 W 0.00 1219.22 3283.41 62.50 304.00 2282.00 1069.31 N 1634.01 W 0.00 1402.14 Top K-15 3500.00 62.50 304.00 2382.01 1176.74 N 1793.28 W 0.00 1541.93 4000.00 62.50 304.00 2612.88 1424.74 N 2160.96 W 0.00 1864.65 4188.67 62.50 304.00 2700.00 1518.32 N 2299.70 W 0.00 1986.43 Build 4/100 4226.17 64.00 304.00 2716.88 1537.05 N 2327.46 W 4.00 2010.79 4264.67 65.54 304.00 2733.29 1556.52 N 2356.34 W 4.00 2036.13 EOC 4500.00 65.54 304.00 2830.73 1676.31 N 2533.93 W 0.00 2192.00 4908.81 65.54 304.00 3000.00 1884.40 N 2842.43 W 0.00 2462.78 Turn 4/100 4915.82 65.54 303.69 3002.90 1887.95 N 2847.72 W 4.00 2467.41 EOC 5000.00 65.54 303.69 3037.76 1930.45 N 2911.48 W 0.00 2522.88 5309.67 65.54 303.69 3166.00 2086.81 N 3146.00 W 0.00 2726.94 Top Ugnu C 5500.00 65.54 303.69 3244.82 2182.92 N 3290.15 W 0.00 2852.36 5903.71 65.54 303.69 3412.00 2386.76 N 3595.89 W 0.00 3118.39 Top Ugnu B 5906.99 65.54 303.69 3413.36 2388.42 N 3598.38 W 0.00 3120.56 Beg Final Bld/Trn 6000.00 66.57 307.60 3451.13 2437.95 N 3667.42 W 4.00 3184.05 6009.76 66.68 308.01 3455.00 2443.45 N 3674.50 W 4.00 3190.96 Top Ugnu A 6100.00 67.78 311.74 3489.94 2496.79 N 3738.33 W 4.00 3257.02 6200.00 69.09 315.80 3526.71 2561.12 N 3805.46 W 4.00 3334.52 6300.00 70.50 319.79 3561.25 2630.63 N 3868.48 W 4.00 3416.18 6400.00 72.00 323.71 3593.40 2704.98 N 3927.07 W 4.00 3501.59 6496.44 73.51 327.42 3622.00 2780.93 N 3979.13 W 4.00 3587.12 K13 6500.00 73.57 327.56 3623.01 2783.82 N 3980.96 W 4.00 3590.34 6600.00 75.21 331.35 3649.92 2866.75 N 4029.89 W 4.00 3681.99 6700.00 76.92 335.08 3674.01 2953.37 N 4073.61 W 4.00 3776.11 All data is in feet unless otherwise stated. Coordinates from slot #174 and TVD from Est. RKB (D-141) (87.00 Ft above mean sea level) . Bottom hole distance is 9932.26 on azimuth 327.53 degrees from wellhead. Total Dogleg for wellpath is 147.57 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 347.31 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ O ,."\ ~ ~ J , "', ,),'~,,~'~ , i.r I ' ,d.!¡ ~ .', , , ' J .,' i i ,~: ~A ~ 4:~i !'''~ b 0\ ~""':,.' ,'~~",\""",~ ., L I'" ~1 i j \} l~ì., ' , All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot *174 and TVD from Est. RKB (D-141) (87.00 Ft above mean sea level). Bottom hole distance is 9932.26 on azimuth 327.53 degrees from wellhead. Total Dogleg for wellpath is 147.57 degrees. Vertical section is from NO. 00 EO. 00 on azimuth 347.31 degrees. Gr id is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) ) ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 2 Pad 1C. 174 Your ref 1C-174 Vers#1. c Kuparuk River Unit, North Slope. Alaska Last revised : 20-Jan-2003 Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID COO R D S G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE S Easting Northing COO R DIN ATE S 6800.00 78.67 338.75 3695.16 3043.27N 4111.92W 557998.89 5971788.89 n70 20 00.76 w149 31 46.21 6900.00 80.47 342.39 3713.27 3136,00N 4144.62W 557965.44 5971881.34 n70 20 01. 67 w149 31 47.16 6976.41 81. 87 345,14 3725.00 3208.49N 4165.73W 557943.74 5971953.65 n70 20 02.38 w149 31 47.78 7000.00 82.31 345.98 3728.25 3231.11N 4171.55W 557937.73 5971976.22 n70 20 02.60 w149 31 47.95 7037.16 83.00 347.31 3733.00 3266.97N 4180.07W 557928.93 5972012.01 n70 20 02.96 w149 31 48.20 7037.18 83.00 347,31 3733.00 3266.99N 4180.07W 557928.93 5972012.03 n70 20 02.96 w149 31 48.20 7332.58 83.00 347.31 3769.00 3553.02N 4244.49W 557862.19 5972297.50 n70 20 05.77 w149 31 50.09 7488.48 83.00 347.31 3788.00 3703.98N 4278.49W 557826.97 5972448.16 n70 20 07.25 w149 31 51.08 7500.00 83.00 347.31 3789.40 3715.13N 4281. OOW 557824.37 5972459.29 n70 20 07.36 w149 31 51.15 7579.59 83.00 347.31 3799.10 3792.20N 4298.35W 557806.39 5972536.21 n70 20 08.12 w149 31 51.66 7659.59 85.00 347.31 3807.46 3869.82N 4315.83W 557788.28 5972613.67 n70 20 08.89 w149 31 52.17 7759.59 87.50 347.31 3814.00 3967.15N 4337.76W 557765.57 5972710,82 n70 20 09.84 w149 31 52.81 7830.39 89.27 347.31 3816.00 4036.19N 4353.30W 557749.46 5972779.72 n70 20 10.52 w149 31 53.27 7859.59 90.00 347.31 3816.19 4064.68N 4359.72W 557742.81 5972808.15 n70 20 10.80 w149 31 53.46 7959.59 92.50 347.31 3814.00 4162.21N 4381.68W 557720.06 5972905.49 n70 20 11.76 w149 31 54.10 7993.19 93.34 347.31 3812.29 4194.94N 4389.06W 557712.42 5972938.16 n70 20 12.08 w149 31 54.32 8000.00 93.34 347.31 3811.90 4201.57N 4390.55W 557710.88 5972944.78 n70 20 12.15 w149 31 54.36 8221. 40 93.34 347.31 3799.00 4417.20N 4439.11W 557660.57 5973159.98 n70 20 14.27 w149 31 55.78 8461.65 93.34 347.31 3785.00 4651.18N 4491. 81W 557605.98 5973393.50 n70 20 16.57 w149 31 57.32 8500.00 93.34 347.31 3782.77 4688.53N 4500.22W 557597.26 5973430.78 n70 20 16.94 w149 31 57.57 8901. 97 93.34 347.31 3759.35 5080.01N 4588.38W 557505.93 5973821.49 n70 20 20.79 w149 32 00.15 8935.57 92.50 347.31 3757.64 5112.74N 4595.76W 557498.29 5973854.16 n70 20 21.11 w149 32 00.36 9035.57 90.00 347.31 3755.45 5210.27N 4617.72W 557475.53 5973951. 50 n70 20 22.07 w149 32 01.01 9064.77 89.27 347.31 3755.64 5238.75N 4624.14W 557468.89 5973979.93 n70 20 22.35 w149 32 01.19 9135.57 87.50 347.31 3757.64 5307.79N 4639.69W 557452.78 5974048.83 n70 20 23.03 w149 32 01. 65 9202.77 85.82 347.31 3761.55 5373.24N 4654.42W 557437.51 5974114.15 n70 20 23.67 w149 32 02.08 9304.97 85.82 347.31 3769.00 5472.68N 4676.82W 557414.31 5974213 .39 n70 20 24.65 w149 32 02.74 9500.00 85.82 347.31 3783.22 5662.44N 4719.56W 557370.04 5974402.78 n70 20 26.51 w149 32 03.99 9565 _ 64 85.82 347.31 3788.00 5726 .3 ON 4733.94W 557355.14 5974466.52 n70 20 27.14 w149 32 04.41 9661.70 85.82 347.31 3795.00 5819.77N 4754.99W 557333.33 5974559.80 n70 20 2$.06 w149 32 05.03 9949.80 85.82 347.31 3816.00 6100.08N 4818.12W 557267.93 5974839.56 n70 20 30.82 w149 32 06.87 10000.00 85.82 347.31 3819.66 6148.92N 4829.12W 557256.53 5974888.31 n70 20 31.30 w149 32 07.20 10148.56 85.82 347.31 3830.49 ' 6293. 46N 4861.67W 557222.81 5975032.57 n70 20 32.72 w149 32 08.15 10215.76 87.50 347.31 3834.40 6358.91N 4876.41W 557207.54 5975097.88 n70 20 33.36 w149 32 08.58 10301.36 89.64 347.31 3836.54 6442.38N 4895.21W 557188.06 5975181.20 n70 20 34.18 w149 32 09.13 10315.76 90.00 347.31 3836.59 6456.43N 4898.37W 557184.79 5975195.22 n70 20 34.32 w149 32 09.22 10415.76 92.50 347.31 3834.40 6553.96N 4920.34W 557162.03 5975292.55 n70 20 35.28 w149 32 09.87 10458.96 93.58 347.31 3832.11 6596.04N 4929.82W 557152.21 5975334.55 n70 20 35.70 w149 32 10.14 10500.00 93.58 347,31 3829.55 6636.01N 4938.82W 557142.89 5975374.44 n70 20 36.09 w149 32 10.41 10669.00 93.58 347.31 3819.00 6800.55N 4975.87W 557104.50 5975538.67 n70 20 37.71 w149 32 11.49 10973.30 93.58 347.31 3800.00 7096.84N 5042.60W 557035.37 5975834.37 n70 20 40.62 w149 32 13.45 11000.00 93.58 347.31 3798.33 7122.84N 5048.46W 557029.31 5975860.32 n70 20 40.88 w149 32 13.62 11387.03 93.58 347.31 3774.16 7499.67N 5133.32W 556941. 39 5976236.41 n70 20 44.58 w149 32 16.10 11430.23 92.50 347.31 3771.87 7541.75N 5142.80W 556931.57 5976278.41 n70 20 44.99 w149 32 16.38 11530.23 90,00 347,31 3769.69 7639.28N 5164.77W 556908.81 5976375.75 n70 20 45.95 w149 32 17.02 11537.03 89.83 347.31 3769.70 7645.91N 5166.26W 556907.27 5976382.37 n70 20 46.02 w149 32 17.07 11630.23 87.50 347.31 3771,87 7736.80N 5186,73W 556886.06 5976473.08 n70 20 46.91 w149 32 17.67 11730.23 85.00 347.31 3778.41 7834,14N 5208.65W 556863.35 5976570.23 n70 20 47.87 w149 32 18.31 11816.36 82.85 347.31 3787.53 7917.70N 5227.47W 556843.85 5976653.62 n70 20 48.69 w149 32 18.86 11820.15 82.85 347.31 3788.00 7921. 36N 5228.29W 556843.00 5976657.28 n70 20 48.73 w149 32 18.88 O {ì ;: /'~ :' 1\¡ 0/ ! ,.cf ri < ~,i: '.j , "'\Aß1'~ J?I:S All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #174 and TVD from Est. RKB (D-141) (87.00 Ft above mean sea level). Bottom hole distance is 9932.26 on azimuth 327.53 degrees from wellhead. Total Dogleg for wellpath is 147.57 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 347.31 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 3 Pad 1C,174 Your ref 1C-174 Vers#1.c Kuparuk River Unit,North Slope, Alaska Last revised : 20-Jan-2003 Measured Inc1in Azimuth True Vert R E C TAN G U L A R G RID COO R D S G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE S Easting Northing COO R DIN ATE S 11964.70 82.85 347.31 3806.00 8061. 29N 5259.81W 556810.35 5976796.93 n70 20 50.10 w149 32 19.81 12000.00 82.85 347.31 3810,40 8095.45N 5267.50W 556802.38 5976831. 03 n70 20 50.44 w149 32 20.03 12133.30 82.85 347.31 3827.00 8224.49N 5296.56W 556772.28 5976959.81 n70 20 51.71 w149 32 20.88 12293.92 82.85 347.31 3847.00 8379.96N 5331.58W 556736.00 5977114.98 n70 20 53.24 w149 32 21. 91 12293.94 82.85 347.31 3847,00 8379.98N 5331.58W 556736.00 5977115.00 n70 20 53.24 w149 32 21. 91 ) ) CmotBd by bmlchcol For: S Shultz Data plotted : 2D-Jan-20D3 Plot Reference 18 1C-174 Vel"Zl#1.c Coordinates are in feet reforence slot 1174. Truo Vortlcal Dopths aro ",r.ronc. Est. RKB (0-141). ... ~ iNT£Q ______.ø__" TD LOCATION: 1640' FSL, 1083' FWL SEC. 35, T12N, R10E 7500 7000 6500 ) ConocoPhillips Alaska, Structure: Pad 1 C Well: 174 Field : Kuparuk River Unit Location: North Slope. Alaska Inc. ) y ConocoPhiliips / - 9000 - 8500 - 8000 - 7500 - 7000 - 6500 - 6000 - 5500 - 5000 ^ I - 4500 Z 0 ., -+- ::J - 4000 r--. -+, CD CD - 3500 -+- '---" - 3000 - 2500 - 2000 -1500 -1000 - 500 0 500 500 pt 347.31 AZIMUTH 9347' (TO TD) ***Plane of Proposal*** C-4 Inverted (Base D) (Base C) , C-2 Inverted (Base D) (Base C) Build 9 5/8 Csg - EOC TOP WEST SAK 0 I "\ t Top West Sak 0 1749' FSL, 2245' FWL SEC. 2, T11N, R10E K13 TO~e~gF-\~o¿ Bld/Tm ~O Top Ugnu B Ö:e..9 Top Ugnu C 4..? E~uCrn 4/100 ~ <f TRUE ESTIMATED SURFACE LOCATION: 1458' FNL, 1129' FWL SEC. 12, T11N, R10E 6000 5500 4000 3500 3000 5000 4500 < - West (feet) O R ' ,r~~ q fi ,~ 11 ! 'I .r, ;: n ,J j~ ., '1' .G l ':,1 i "~ \",/ Y..A, ' " ~ v,. :1 ',~, ",~ 2500 2000 1500 500 1000 Created by bmichael For: S Shultz Date plaUed : 20-Jan-2003 Plat Rererence is 1 C-174 Ve",l1.c Coordlnales ore in feet reference slot ;¡174. True Vertical Depths are reference Est. RKB (0-141). .. -=.s INT~Q 450 - 0 - ! 450 - ---.. 900 - <J +- Q) Q) =tJ - 1350 - '-"' ~-~-:_,",:J ..c Ç". ~~ +- ,< 0... ~~~ J Q) 1800 - Ii!b~~~ 0 '~'..~ ;r. -- ~- 0 2250 - ~ u t r-- Q) > 2700 - Q) ::J I.... 3150 - ~ I V 3600 - 4050 - 4500 - 4950 450 Est. RKB Elevation: 87' KOP 2.00 tgg DLS: 2.00 deg per 100 ft Curve 4/100 11.93 15.90 1i3~J6 DLS: 4.00 deg per 100 ft 31.84 39.83 47.82 55.8~OC Base Permafrost o 900 1800 1350 450 ConocoPhillips Alaska, Inc. Structure: Pad 1C Well: 174 I Field : Kuparuk River Unit Location: North Slope. Alaska I 347.31 AZIMUTH 9347' (TO TD) ***Plane of Proposal*** TANGENT ANGLE 62.50 DEG TANGENT ANGLE 65.54 DEG \"- \00 e< Build 4/100 >.(>.'0 ç 64.00 EOC IjV f>t90 ïurn 4/100 <vS' c--;") <)ì mc ~ ~ ~ ïop Ugnu C ~ () 1(?ó'2>òl;SP'2> 00 ïop Ugnu B cp .~ò ?--is ?--ei ~\'\ Be~ Final Bld/Trn ~e'2>'- 1>'>-'\ ,\<;>-4e ,\ç-.-4'ô <'},. Top Ugnu A '" '\ '\ ~ç-. 00 R:> '1- <'}, 0<:( oÇ¡ ~13 ,,0<:( c,<¢"'1>e;'ò'J' x.-0 <çj c..'" Ç¡< «;: -V · "". '" x.-0c.. c..".>Q, ~\'ò q¡ 2250 2700 3600 4050 4500 5400 5850 6300 6750 3150 4950 Vertical Section (feet) -> Azimuth 347.31 with reference 0.00 N, 0.00 E from slot #174 ~ ConocoPhillips ",'? c.. e,GÌ e()ì 1>0<:> 1(?0".> ò~ er> R ,)~ò oJ.'ò<,,-e oJ.e~ Ç¡<o <Q \Ç\ \<;> \Ç\ <>.",'? <>.e/P o<¢ ",f>t c../bt <¢eOJ x.-0() "'~ b v v «;: <¢ c..«¡", .. ------. «'- c..".>0; '" "Ç¡ 7200 7650 8100 8550 9000 ,~. "~' 9450 9900 ! • ConocoPhillips Alaska, Inc. , _ I c.eaeea oy em~~noei For: S Shultz ~ I ~?' '~~ ~"~ ~?' I s I~~ S}ructure : Pad 1 C Well : 174 oae niottea , zo-ao~-2ooa ~ I Pbl Re(ercnce ia 1C-174 Vm~1.c Field : Kuporuk River Unit Location : Norfh Slope, Alaska I Coordinate orc in feet Merenx alot /174. ' Trve VaNCaI OepN9 or=rNerenm Es[. RKB (0-141).I ~_ .-.jY4.vr~-._--___- _"~. Q ~ ~ 440 \ ~ \V 420 ~ 400 ~ 380 ~ i / 360 ~/ 340 ( ~ I i00 ___ -- - --- % - 12 320 / /~ 300 l ~ zao n I i ~ 260 ~ ~ ,~ 1900 ~ ~ S ~ 240 ~~ N CD /~ / / ~J 220 ~ 200 I j 180 300 j ,~ 1700 % , t so .I ' ' ~/900 140 ~ ~ T ~1300 . ~ ~ 720 ~~4 9G .100 . ~~°~' * 4700 ,~ 15fl0 ,~ 700 \ 2900 100 *-4300 ~ ,~~3900 ~~ qG~ `~ ~ ~300'~, 1300 ~ 80 ,~.. 4, ~~... .. 1100 ~~~~ ~8 ~ 4-, ° 60 540 520 500 4B0 460 440 420 400 380 360 340 320 300 280 260 240 220 20 0 <- West (feet) OR~~~~'~~L ~ • CI onocoPhillips Alaska, Inc. ~ i_ __ creacm oy omtcn«i ~ ~ ~~' For: S Shultz Structure : Pad 1 C Well : 174 ~~n~~~~~ ~' la'~ ~ Oole P~~ : 20~1on-200] ~ Plv[Refeeenceie~c-i~ava./i.~ Field : Kuparuk River Unit Location : North Slope, Alaska CoorAinatos are in (est Meronu slo[ /174. T~ve Vertbol papW ara raferenm Fat. RKB (0-141). ~~ ~ L-__ =•T~^_~ Q 920 , , soo aao I eao 1700 sDo '~ ~so ' * 1600 720 680 j, 1500 640 n 600 ~ ~ Z O ~ 1400 560 ~ ~p 3' I ~ ~ 'I 520 ~ \ ~ 1300 ~ ~ 1700 \ ~ 480 \ ~ 1200 440 ~~ 600 00 ~ ~1100 400 ~ 150~7~ 3 0 360 600 'F ~ 4 900~ ~e 320 \~~ 800# ~~ JO ~, 700 280 ,~gap ~, 600 1 ~~0 ~ •` 1700 E+~ SOO 2a0 1500 ~ ` 200 ~o~' ~~ O~oR ' ~ °~ 1120 1080 1040 10D0 960 920 880 840 800 760 720 680 640 600 560 520 480 <- West (feet) ~~'~~~-1 f~~~l c..~.e ey emi~na.i For: S Shultz oam Pio~~a : 2o-da~-zooa ! Plot Rafanncs i~ tC-1]4 Vsn~1.c CwrEinalp orc in fat reMrenca elot /1]4. ~Tr~e Vertical Depiha aro rcfererce FiL RK8 (D-141J. ~ ~ ~ i7;F~v ~_ ~ • CoaZOCOPhillips Alaska, Inc. Structure : Pad 1 C Well : 174 Field : Kuparuk River Unit Location : North Slope, Alaska ~- ~ a= ~~~~~c~r~l~il~~ 9500 9000 8500 8000 7500 7000 6500 6000 n 5500 ~ Z O ~ 5000 ~ i--~ ~ 4500 ~ (D ~ ~ 4000 3500 3000 2500 2000 1500 1000 500 o~e~~~~~r~~ 9500 9000 B500 8000 7500 7000 6500 6000 5500 5000 4500 4000 35D0 3000 2500 2000 1500 <- West (feet) ~ • - c.~esa er em~~na>i For: S Shultz oa~ vioeese : m-~a~-zoa} Plot Reference Is iC-171 VersR1.c CoorEinatea arc in feM referance alol /1]1. ~True Verticol 0.qN~ me rolaienm Eat. RKB (0-141). ~ iis ~ 1„7~ ConocoPhillips Alaska, Inc. Structure : Pad 1 C Well : 174 Field : Kuparuk River Unit Locaiion : North Slope, Alaska ~ ~~~a=~~=~-:l~~l~~ 2300 2200 2100 2000 1900 1800 1700 1600 n 1500 I Z O ~ 1400 ~ ~ ~ 1300 ~ CD ~ ~ 1200 1100 7000 9D0 800 7D0 600 500 2500 2400 2300 2200 2100 2000 1900 1800 1700 ~600 1500 1400 1300 1200 1100 1000 900 800 <- West (feet) ORr~I~~~,~~ ~ • ConocoPhillips Alaska, Inc. _ _- ~~ c~eat~a cy nm~~naei For: 5 Shultz ~~, Siructure : Pad 1 C Well : 174 4's`r ~~~~''~'?-~ oae c~aesa : zo-.w~-zooa ~ v~a R~r~.«,~ ~s ic-na va,,;{i.~ Field : Kuparuk River Unit Location : Norfh Slope, Alaska Gatli~wtd ae in fttt reteronce abt Y77{. r~ v.rowi o~n~ me refarerrce Eat. RKB (D-141). ~ ~ ini ` ---- TRUE NORTH ~ 290 280 270 260 250 L Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well 70 80 90 100 110 J 4R~~~~~'~~~~ ...../ ConocoPhillips ConoeoPhillips Alaska Ine Structure : Pad 1 C Well: 174 Field : Kuparuk River Unit Location : North Slope, Alaska PROFILE COMMENT DATA For: S Shultz Dote plotted: 20-Jan-2003 ft Reference is 1C-174 Versl1.e Coordinates ore in feet reference slot j174. True Vertical Depth. ore reference Est. RKB (D-14 ulr -- INTF.Q Point -- ~ Deg/1 00 0.00 2.00 4.00 0.00 0.00 0.00 0.00 4.00 0.00 4.00 0.00 0.00 0.00 4.00 4.00 4.00 4.00 0.00 0.00 0.00 2.50 0.00 0.00 0.00 2.50 0.00 0.00 0.00 2.50 0.00 0.00 0.00 2.50 0.00 0.00 0.00 v. Sect 0.00 15.87 552.64 648.72 1003.77 1402.14 1986.43 2036.13 2462.78 2467.41 2726.94 3118.39 3120.56 3190.96 3587.12 4045.22 4105.43 4398.64 4553.39 4643.81 5056.64 5284.46 5524.31 5963.87 6264.45 6722.16 7009.50 7207.72 7517.88 7727.52 8031.22 8444.14 8872.64 9019.82 9187.11 9346.48 East 0.00 -25.85 -666.14 -775.62 -1180.13 -1634.01 -2299.70 -2356.34 -2842.43 -2847.72 -3146.00 -3595.89 -3598.38 -3674.50 -3979.13 -4165.73 -4180.07 -4244.49 -4278.49 -4298.35 -4389.06 -4439.11 -4491.81 -4588.38 -4654.42 -4754.99 -4818.12 -4861 .67 -4929.82 -4975.87 -5042.60 -5133.32 -5227.47 -5259.81 -5296.56 -5331.58 North 0.00 10.44 416.4 7 490.32 763.16 1069.31 1518.32 1556.52 1884.40 1887.95 2086.81 2386.76 2388.42 2443.45 2780.93 3208.49 3266.97 3553.02 3703.98 3792.20 4194.94 4417.20 4651.18 5080.01 5373.24 5819.77 6100.08 6293.46 6596.04 6800.55 7096.84 7499.67 7917.70 8061.29 8224.49 8379.96 TVD 200.00 598.70 1674.26 1743.00 1997.00 2282.00 2700.00 2733.29 3000.00 3002.90 3166.00 3412.00 3413.36 3455.00 3622.00 3725.00 3733.00 3769.00 3788.00 3799.10 3812.29 3799.00 3785.00 3759.35 3761.55 3795.00 3816.00 3830.49 3832.11 3819.00 3800.00 3774.16 3787.53 3806.00 3827.00 3847.00 Dir 292.00 292.00 304.00 304.00 304.00 304.00 304.00 304.00 304.00 303.69 303.69 303.69 303.69 308.01 327.42 345.14 347.31 347.31 347.31 347.31 347.31 347.31 347.31 347.31 347.31 347.31 347.31 347.31 347.31 347.31 347.31 347.31 347.31 347.31 347.31 347.31 Inc 0.00 8.00 62.50 62.50 62.50 62.50 62.50 65.54 65.54 65.54 65.54 65.54 65.54 66.68 73.51 81.87 83.00 83.00 83.00 83.00 93.34 93.34 93.34 93.34 85.82 85.82 85.82 85.82 93.58 93.58 93.58 93.58 82.85 82.85 82.85 82.85 MD 200.00 600.00 1967.24 2116.11 2666.20 3283.41 4188.67 4264.67 4908.81 4915.82 5309.67 5903.71 5906.99 6009.76 6496.44 6976.41 7037.16 7332.58 7488.48 7579.59 7993.19 8221.40 8461.65 8901.97 9202.77 9661.70 9949.80 0148.56 0458.96 0669.00 0973.30 1387.03 1816.36 1964.70 2133.30 2293.92 1 1 1 1 1 1 1 1 1 KOP Curve 4/100 EOC Base Permafrost Top T-3 Top K-15 Build 4/100 EOC Turn 4/100 EOC Top Ugnu C Top Ugnu B Beg Final Bld/Trn Top Ugnu A K13 Top West Sak 0 9 5/8 Csg - EOC C-1 B-1 Begin Build EOB B-2 Inverted(BaseC) C-2 Inverted(BaseD) Drop 2.5/100 EOD C-3 B-3 Begin Build EOB B-4 Inverted(BaseC) C-4 Inverted(BaseD) Begin Drop EOD C-5 8-5 TD - Csg pt C') ;:r~:J ....C'"_ f~-) ~;~""""-~:I .;:;.-:: - ->~j -~ . .~":-.~ ~ ~ BJ~KEIt ~~~ IN 1~ N: `) Measured Angle SVY# Depth deg Tie-In 0.00 0.00 1 100.00 0.00 2 200.00 0.00 3 300.00 2.00 4 400.00 4.00 5 500.00 6.00 6 600.00 8.00 7 700.00 11.93 8 800.00 15.90 9 900.00 19.87 10 1000.00 23.86 11 1100.00 27.85 12 1200.00 31.84 13 1300.00 35.83 14 1400.00 39.83 15 1500.00 43.83 16 1600.00 47.82 17 1700.00 51.82 18 1800.00 55.81 19 1900.00 59.81 20 1967.24 62.50 21 2000.00 62.50 22 2500.00 62.50 23 3000.00 62.50 24 3500.00 62.50 25 4000.00 62.50 26 4188.67 62.50 27 4226.17 64.00 28 4264.67 65.54 29 4500.00 65.54 30 4908.81 65.54 31 4915.82 65.54 32 5000.00 65.54 33 5500.00 65.54 34 5906.99 65.54 35 6000.00 66.57 36 6100.00 67.78 37 6200.00 69.09 38 6300.00 70.50 39 6400.00 72.00 40 6500.00 73.57 41 6600.00 75.21 42 6700.00 76.92 43 6800.00 78.67 44 6900.00 80.47 45 7000.00 82.31 46 7037.18 83.00 47 7500.00 83.00 48 7579.59 83.00 49 7659.59 85.00 50 7759.59 87.50 51 7830.39 89.27 52 7859.59 90.00 53 7959.59 92.50 54 7993.19 93.34 ~ 1 C-174 V8 Ver#1.6 January 09, 2003 Azimuth deg 0.0( 292 A( 292.0( TVD-RKB Alaska State Plane Zone ~4 Nad 27 Coordinates TVD X Y Subsea ft ft 0.00 -87.00 562135.02 5968779.~i~1 100.00 13.00 562135.02 5968779 .~4 200.00 113.00 562135.02 5968779 .44 299.98 212.98 562133.39 5968780 .Q~L~ 399.84 312.84 562128.52 5968782 00 499.45 412.45 562120.42 5968785 20 598.70 511.70 562109.08 5968789 .G" 697.17 610.17 562093.31 5968796 74 79422 707 889 37 80~ 982.16 89` 1072.13 98~ 1158.85 1071 1241.89 1154 1320.86 1233 1395.36 130E 1465.03 137~ 1529.54 1442 1588.57 1501 1641.82 1554 167426 1587 1689.39 1602 1920.26 1833 2151.13 2064 2382.01 2295 2612.88 2525 2700.00 2613 2716.88 2629 2733.29 2646 2830.73 2743 3000.00 2913 3002.90 2915 3037.76 2950 3244.82 3157 3413.36 3326 3451.13 3364 3489.94 3402 3526.71 3439 3561.25 3474 3593.40 3506 3623.01 3536 3649.92 3562 3674.01 3587 3695.16 3608 371327 3626 372825 3641 3733.00 3646 3789.40 3702 3799.10 3712 3807.46 3720 3814.00 3727 3816.00 3729 3816.19 3729 3814.00 3727 381229 3725 22 562071.93 5968807.72 37 562045.05 5968822.54 16 562012.79 5968&41.1a 13 561975.33 5968863.~14 85 561932.83 5968889.3~ 89 561885.51 5968918.G"f 86 561833.59 5968951.'~5 36 561777.34 5968987.a3 03 561717.02 5969025.79 54 561652.93 5969067.?F3 57 561585.37 5969111.46 82 561514.69 5969157.96 26 561465.57 5969190.=4=1 39 561441.35 5969206.~9 26 561071.70 5969451.~8 13 560702.05 5969696.46 D1 560332.40 5969941.45 68 559962.75 5970186.~b3 ~0 559823.27 5970278.8~ B8 559795.36 5970297.3~ 29 559766.33 5970316.6"d 73 559587.79 5970434.93 ~0 559277.64 5970640.48 90 559272.31 5970643.u9 76 55920822 5970685.ut3 32 558827.55 5970935.:;3 36 558517.69 5971138.~~t~ 13 558448.25 597118727 a4 558376.87 5971245.51 71 55830923 5971309.29 25 558245.65 5971378.28 ~0 558186.46 5971452.1 ~ )1 558131.93 5971530.a3 32 558082.34 5971613.G6 )1 558037.92 5971699.32 16 557998.89 5971788 89 ?7 557965.44 5971881.34 ?5 557937.73 5971976.~2 )0 557928.93 5972012.0~ l0 557824.37 59724592~ 10 557806.39 5972536.29 ~6 557788.28 5972613.G7 )0 557765.57 597271Q.&2 )0 557749.46 5972779.72 19 557742.81 5972808.'I > )0 557720.06 5972905.~49 ?9 557712.42 5972938.16 ~ N / -S ft 0.00 2.61 5.88 10.44 17.65 28.80 43.84 62.71 85.30 111.52 141.22 174.28 210.52 249.77 291.83 336.51 383.59 416.47 432.72 680.73 928.73 1176.74 1424.74 1518.32 1537.05 1556.52 1676.31 1884.40 1887.95 1930.45 2182.92 2388.42 2437.95 2496.79 2561.12 2630.63 2704.98 2783.82 2866.75 2953.37 3043.27 3136.00 3231.11 3266.99 3715.13 3967.15 4036.19 4064.68 4162.21 4194.94 VSect. Plane = 347.31 E / -W DLS ft deg/100 ft 0.00 0.00 0.00 0.00 0.00 0.00 -1.62 2.00 -6.47 2.00 -14.55 2.00 -25.85 2.00 -41.57 4.00 -62.86 ~ 4.00 -89.63 4.00 -121.73 4.00 -159.02 4.00 -201.31 4.00 -248.39 4.00 -300.04 4.00 -356.01 4.00 -416.02 4.00 -479.78 4.00 -546.98 4.00 -617.29 4.00 -666.14 4.00 -690.23 0.00 -1057.92 0.00 -1425.60 0.00 -1793.28 0.00 -2160.96 0.00 -2299.70 0.00 -2327.46 4.00 -2356.34 4.00 -2533.93 0.00 -2842.43 0.00 -2847.72 4.00 -2911.48 0.00 -3290.15 0.00 -3598.38 0.00 -3667.42 4.00 -3738.33 4.00 -3805.46 4.00 -3868.48 4.00 -3927.07 4.00 -3980.96 4.00 -4029.89 4.00 -4073.61 4.00 -4111.92 4.00 -4144.62 4.00 -4171.55 4.00 -4180.07 4.00 -4281.00 0.00 -4298.35 0.00 -4315.83 2.50 -4337.76 2.50 -4353.30 2.50 -4359.72 2.50 -4381.68 2.50 -4389.06 2.50 o~~~~r~;~~~ ) ConocóPhillips ) Conoco/Phillips, Inc. Post Office Box 1 00360 Anchorage, Alaska 99510 January 3, 2003 Ms. Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill: 1C-174 (Undulating Injector) / Surface Location: Target Location: Bottom Hole Location: 1503' FNL, 1195' FWL, Sec 12 T11 N, R10E, UM 3532' FNL, 2246' FWL, Sec 2, T11 N, R10E, UM 3639' FNL, 1083' FWL, Sec 35, T12N, R10E, UM Dear Commissioner: / Conoco/Phillips Alaska, Inc. hereby applies for a "permyo Drill" to drill the injector well 1 C-17 4. The well will be drilled and completed using Doyon #141. Please utilize documents on file for this rig. The following logs are to be run on this well: GR/Res. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 1 C, or hauled to an approved Prudhoe or GKA Class II disposal well. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report (20 AAC 25,070) Sharon Allsup-Drake, Drilling Technologist 263-4612 B) Geologic Data and Logs (20AAC 25.071) Mike Werner, Geologist 265-6191 If you have any questions or require further information, please contact Steve Shultz at (907) 263-4620. Sincerely, '\ "-~ \~- R. Thomas Kuparuk Drilling Superintendent i '\ì 1.....1 ~.~ 'J' ,¡n' :ur'o,;, ,:,'i,,::,.:;" ¡ -~"I"'C; ~~ (lS~\"l ~;t ~Il ~..."~l,",,,~ ~.L~I ,\..ill RECE1V[:Ð Ftb 0 4 2.003 A\aska ou & Gas Cons. comro\sslo.n AnCborag,a I I co.,,, ","""'~ ,,," US~ NA Valid Up To 5000 Dollars 1// / i ~ 0 CHASE '''~hO~''"·'''-''''''''''__$£~dd¥_1J* 11 MEMO ! 2 7 2 5 7111 ¡. 0 2 b , "_'~""',",_,:",~"...",_", , i 0 ~ I, I, ," 2 ~ 8 0 0 0 0 I, .. _ '_.~ _~_~"""""..,.""=,~.." u. _",,~ "~,¡;!:~t<:1"'\~~'~'1I'~w""'~"¡:~'~'1!"~~"~''':~~''\~'~''''"-,,.. "1':,:,:\1"), ...,,,,,,,,,,,,,,,",,,",,:,,,,j'é"'" ,'"n'"\'''7',",'''::~'':'''i'},n':'~'''''ì''~''' ," ~ ,,'., ,.. " , T~~;;;;;;;;:::~:W»'~~"¢~'»'";"'--=-~'""~'----7~:~1 ~~c~~k:J~ ~~3~9501 DATE ~~ y~ I tÎ;, 2ø3 i 1 T 62-14(311 f ~ ÞAY TO THE >rJtTG-oÇ LLI iA-rCff /A-~C/"' I $ 100 ....)0 ~, i ORDER OF r¡ '--' t.;:. '-C::.l '-- . . v ¡ \ ~Ck Lkl rLC(¡.<; J /&^ojoo fÐ 0.",",,"''''''.' . I Indt,ldfld DOLLARS 0",,,,,,,",,, ') ) ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API num ber last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the, original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST ' CÖMPANY..D1~~Á)!lJ WELL NAME;Ç&¡ / G- /}éf FIELD & POOL . ~ 7- Ò I,. <) 0 INIT CLASS J,~ O\"';J ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. . . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. .'. . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . (Service Well Only) 13. Well located w/in area & strata authorized by injection order # 2. l> (Service Well Only) 14. All wells w/in % mile area of review identified. . . . . . . . .. ENGINEERING APPR DATE /f¿ &03 APPR DATE \~G14- z/t;/o 3 . (Service Well Only) GEOLOGY APPR DATE Æ'fJc: 2/';I;0'~ ' rE~ploratory Only) 15. Conductor string provided. . .. . . . . . . . . . . . . . . . 16. Surface casing protects all known USDWs. . . . . . . . . . . 17. CMT vol adequate to circulate on conductor & surf csg. . . . . 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 19. CMT will cover all known productive horizons. . . .. . . .. . 20. Casing designs adequate for C, T, B,& permafrost. . . . . . . 21. Adequate tankage or reserve pit. . . . . . . . . . . . . . . . . 22. If a re-drill, has a 10-403 for abandonment been approved. . . 23. Adequate wellbore separation proposed.. .'.' . . . . . .. . . 24. If diverter required, does 'it meet regulations. .. . . . . .. . 25, Drilling fluid program schematic & equip list adequate. . . . . 26. BOPEs, do they meet regulation. . . . ',. . . . . . . . . . . 27. BOPE press rating appropriate; test to 3S 00 psig. 18. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 29. Work will occur without operation shutdown. . . . . . . . . . . 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 31. Mechanical condition of wells within AOR verified. . . . . . . . 32. Permit can be issued w/o hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if ,off-shore). . . . . .. ...... 36. Contact namelphone for weekly progress reports. .....,. PROGRAM: Exp _ Dev _ Redrll _ Re-Enter _ Serv ~ Wellbore seg _ GEOLAREA ~76 UNIT# //160 ON/OFFSHORE~ f0N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N ~N Y N Y N rf\~ '¥N ¥-N- . i ~-,--N SLo fte-d -N . N D "'.':1 ev- I Y I ¡\1/H- ) 7/- 0 C? "5 I C;! - 0 z. ~ I c¡ r - 00 '! , 9 '5 - 0 c¡t¡ W· ~o,A f.;lJ~i' ~T 1Jl) /1t:.¿¡ ¡}-i-or) f)l~, /Ij~/~ K¡¿0 llj'13 P ~ A- I \AlII-! ~ " v ~' .N N . N Y11~/"- iYll,J...' tOr ,-I p P c-l . N ¡/)A P' , N ;'l S It.{ ~le ýJ~{,' N rc~f I^ÜÐ(d ç;,Æ ilt~.f:t /1IlO t.. . ),,-tët') f1' ~ i cd I vue! Is. tM) ¡¿WI^- /f-& /2 ' j1Y" ,1U.1i~· . ~ N ' N ' . ( GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Commentsllnstructions: RPrJf¿ TEM JDH JBR COT DTS ð <"Þ7fO J ./' MJW MLB ¿).2/~¿/~3 SFD WGA Rev: 10/15/02 - G:\geology\permits\checklist.doc ) ) We 1/ H ¡story File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to sim,plify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. cLds, Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe 1 Use: ConocoPhillips, Alaska Inc August 9, 2005 7516 1 4.5" 12.6 lb. L-80 NSCT Tubing Well: Field: State: API No.: Top Log IntvI1.: Bot. Log IntvI1.: Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the DB Nipple @ 6,300' (Drillers Depth). 1 C-174 Kuparuk Alaska 50-029-23140-00 Surface 6,638 Ft. (MD) This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the interval of 4.5" tubing logged is in good to poor condition, with a maximum recorded penetration of 42% @ 5,302'. Wall penetrations ranging from 20% to 42% wall thickness are recorded in132 of the 219 joints logged. The damage recorded appears in the form of Lines of Pits and Line Corrosion. There are no areas of significant Cross Sectional Wall loss or I.D. restrictions recorded throughout the interval of tubing logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WAll PENETRATIONS: Line Corrosion Line of Pits Line of Pits Line Corrosion Line of Pits Jt. Jt. Jt. Jt. Jt. 171 @ 137 @ 77 @ 139 @ 75 @ ( 42%) ( 41 %) ( 40%) ( 39%) ( 37%) MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No areas of significant cross-sectional wall loss (>4%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. 5,302 Ft. (MD) 4,259 Ft. (MD) 2,384 Ft. (MD) 4,321 Ft. (MD) 2,313 Ft. (MD) r\·f"'·Æ~~'t.\~..~~r": ~ut; 2; ~) 2JJ05 ~~~ð"",~'.'W'Z~t... f"l I Field Engineer: L Mills-Dawson Analyst: J. Thompson Witness: T. Senden ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@mernorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 _~ ¡ ()~ ,.- ~Àl • • PDS Report Overview ~~ s,,. Body Region Analysis Well: 1 C-174 Survey Date: August 9, 2005 Field: Kuparuk Tool Type: MFC 40 No 99493 Company: CononoPhillips, Alaska Inc Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: J. Thom son Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 4.5 ins 12.6 f L-80 NSCT 3.958 ins 4.5 ins 1.2 ins 1.2 ins Penetration and Metal Loss (% wall) ~ penetration body metal loss body 250 200 150 - 100 -- - 50 -- - - ~ -- 0 to 1 to 10 to 1% 10% 20% 20 to 40 to over 40% 85% 85% Number of 'oints anal se d total = 219 pene. 5 50 32 loss 9 210 0 130 2 0 0 0 0 Damage Configuration ( body ) 200 150 100 50 0 - isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 162 0 0 162 0 0 Damage Profile (% wall) ~ penetration body - metal loss body 0 50 0 48 GLM 1 - 96 146 196 Bottom of Survey = 214 100 Analysis Overview page 2 PDS~PORT JOINT TABI. Pipe: 4.5 in 12.6 ppf L-80 NSCT Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: ~ LATI ON~ EET 1 C-174 Kuparuk CononoPhillips, Alaska Inc USA August 9, 2005 Joint No. Jt. Depth (Ft.) Pen. Upset (Ins.) Pen. Body (Ins.) Pen. % Metal Loss °i4, Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 11 0 0.01 2 ? 3.91 PUP 1 15 0 0.02 8 ~ 3.91 2 49 0 0.01 2 1 3.92 3 78 0 0.05 17 1 3.89 Line shailow corrosion. 4 110 0 0.01 2 ~ 3.92 5 141 0 0.01 ~ 1 3.92 6 172 0 0.01 ~ ' 3.93 7 203 0 0.00 1 ~ 3.93 8 233 0 0.01 3 ' 3.92 9 264 0 0.01 3 1 3.93 10 295 0 0.00 1 1 3.92 11 325 0 0.01 3 ? 3.92 12 356 0 0.01 2 1 3.92 13 386 0 0.01 3 ? 3.92 14 417 0 0.05 18 3 3.91 Line shallow corrosion. 15 448 0 0.01 2 ' 3.93 15.1 479 0 0.01 3 3 3.94 PUP 15.2 485 0 0 0 0 3.81 DB NIPPLE 153 487 0 0.01 4 3 3.92 PUP 16 493 0 0.01 4 ? 3.88 17 525 0 0.01 3 ' 3.91 18 556 0 0.01 4 ~ 3.91 19 588 0 0.01 3 1 3.87 20 617 0 0.01 4 '' 3.92 21 649 0 0.01 ' ' 3.92 22 679 0 0.01 ~ ' 3.91 23 709 0 0.01 3 ? 3.91 24 741 0 0.01 2 1 3.91 25 771 0 0.01 3 ? 3.93 26 802 0 0.02 8 ~ 3.93 27 833 0 0.01 3 ~ 3.91 28 864 0 0.00 1 ~ 3.94 29 895 0 0.01 ? 1 3.92 30 925 0 0.01 4 2 3.93 31 955 0 0.01 ~ 3 3.92 32 986 0 0.01 2 ~ 3.93 33 1016 0 0.02 8 ? 3.92 34 1048 0 0.00 1 2 3.93 35 1078 0 0.06 20 2 3.93 Line of Pits 36 1109 0 0.01 2 "' 3.93 37 1140 0 0.01 2 ~ 3.91 38 1171 0 0.03 12 `' 3.91 Shallow Line of Pits. 39 1200 0 0.03 9 ~ 3.93 40 1231 0 0.01 4 ~ 3.94 41 1262 0 0.03 1' ~ 3.91 Shallow Line of Pits. 42 1294 0 0.01 2 ' 3.93 43 1324 0 0.01 2 ~ 3.93 44 1355 0 0.03 10 ? 3.92 45 1386 0 0.02 8 ? 3.94 46 1416 0 0.00 1 ~ 3.93 Penetration Body Metal Loss Body Page 1 PDS~PORT JOINT TABI. Pipe: 4.5 in 12.6 ppf L-80 NSCT Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: ~ LATI O N~ E ET 1 C-174 Kuparuk CononoPhillips, Alaska Inc USA August 9, 2005 Joint No. Jt. Depth (Ft.) Pen. Upset (Ins.) Pen. Body (Ins.) Pen. %> Metal Loss `;6 Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 94 2909 0 0.07 25 3 3.93 Line of Pits. 95 2940 0 0.07 37 4 3.91 Line Corrosion 96 2972 0 0.07 27 3 3.94 Line of Pits. 97 3002 0 0.07 28 3 3.92 Line of Pits. 98 3033 0 0.07 27 3 3.92 Line of Pits. 99 3061 0 0.08 28 3 3.93 Line of Pits. 100 3092 0 0.06 22 3 3.92 Line of Pits. 101 3122 0 0.08 31 3 3.93 Line of Pits. 102 3154 0 0.07 27 3 3.93 Line of Pits. 103 3184 0 0.08 28 4 3.91 Line Corrosion. 104 3215 0 0.10 36 4 3.91 Line of Pits. 105 3246 0 0.06 22 3 3.92 Line of Pits. 106 3278 0 0.08 30 4 3.92 Line corrosion. 107 3308 0 0.07 26 4 3.91 Line of Pits. 108 3339 0 0.08 30 3 3.90 Line corrosion. 109 3370 0 0.07 24 4 3.93 Line Corrosion. 110 3402 0 0.07 28 4 3.92 Line Corrosion. 111 3430 0 0.09 31 4 3.92 Line Corrosion. 1 12 3461 0 0.08 28 4 3.92 Line corrosion. 1 13 3492 0 0.10 35 4 3.92 Line of Pits. 114 3522 0 0.10 37 4 3.92 Line corrosion. 115 3553 0 0.10 37 4 3.88 Line Corrosion. 116 3585 0 0.07 25 4 3.92 Line of Pits. 1 17 3616 0 0.09 32 4 3.93 Line Corrosion. 118 3646 0 0.08 29 4 3.94 Line of Pits. 119 3678 0 0.09 35 4 3.91 Line Corrosion. 120 3710 0 0.08 29 3 3.92 Line Corrosion. 121 3741 0 0.08 30 4 3.91 Line corrosion. 122 3771 0 0.09 35 4 3.93 Line Corrosion. 123 3802 0 0.10 37 3 3.92 Line Corrosion. 124 3832 0 0.09 33 3 3.92 Line of Pits. 125 3863 0 0.09 35 4 3.92 Line Corrosion. 126 3893 0 0.09 34 4 3.92 Line of Pits. 127 3924 0 0.10 37 4 3.92 Line Corrosion. 128 3954 0 0.10 37 4 3.92 Line of Pits. 129 3985 0 0.10 37 4 3.92 Line Corrosion. 130 4017 0 0.08 31 4 3.92 Line of Pits. 131 4047 0 0.10 38 4 3.90 Line corrosion. 132 4079 0 0.10 37 4 3.91 Line of Pits. 133 4109 0 0.10 36 4 3.93 Line corrosion. 134 4140 0 0.09 32 4 3.92 Line Corrosion. 135 4171 0 0.07 ?7 4 3.93 Line of Pits. 136 4202 0 0.06 23 3 3.92 Line of Pits. 137 4233 0 0.11 41 4 3.91 Line of Pits. 138 4263 0 0.09 32 4 3.88 Line corrosion. 139 4294 0 0.1 1 39 4 3.94 Line corrosion. 140 4325 0 0.08 28 4 3.93 Line of Pits. 141 4356 0 0.08 ?9 3 3.92 Line corrosion. 142 4388 0 0.09 32 4 3.92 Line corrosion. 143 4419 0 0.07 24 3 3.92 Line of Pits. Penetration Body Metal Loss Body Page 3 PDS~PORT JOINT TABI. Pipe: 4.5 in 12.6 ppf L-80 NSCT Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: ~ LATI O N~ E ET 1 C-174 Kuparuk CononoPhillips, Alaska Inc USA August 9, 2005 )oint No. Jt. Depth (Ft.) Pen. Upset (Ins.~ Pen. Body (Ins.) Pen. % Metal Loss °r~> Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 144 4449 0 0.07 27 -~ 3.92 Line of Pits. 145 4480 0 0.10 35 4 3.93 Line corrosion. 146 4510 0 0.06 ?3 3 3.92 Line corrosion. 147 4541 0 0.09 33 4 3.93 Line corrosion. 148 4572 0 0.08 31 4 3.89 Line of Pits. 149 4603 0 0.05 20 3 3.93 Line of Pits. 150 4634 0 0.08 28 3 3.91 Line Corrosion. 151 4664 0 0.06 21 3 3.93 Line of Pits. 152 4695 0 0.08 29 3 3.94 Line of Pits. 153 4726 0 0.09 33 4 3.92 Line of Pits. 154 4756 0 0.09 32 4 3.92 Line corrosion. 155 4788 0 0.06 24 3 3.93 Line of Pits. 156 4818 0 0.07 ?5 3 3.88 Line corrosion. 157 4849 0 0.06 23 4 3.86 Line Corrosion. Lt. De osits. 158 4881 0 0.07 24 4 3.92 Line corrosion. 159 4912 0 0.06 24 3 3.92 Line of Pits. 160 4942 0 0.07 25 3 3.93 Line corrosion. 161 4973 0 0.07 25 3 3.93 Line corrosion. 162 5004 0 0.09 33 4 3.93 Line corrosion. 163 5035 0 0.07 27 4 3.92 Line of Pits. 164 5066 0 0.08 29 3 3.92 Line of Pits. 165 5096 0 0.08 30 3 3.92 Line of Pits. 166 5127 0 0.07 27 3 3.92 Line of Pits. 167 5158 0 0.09 32 4 3.89 Line Corrosion. 168 5189 0 0.09 32 3 3.86 Line corrosion. Lt. De osits. 169 5219 0 0.08 ?9 3 3.92 Line Corrosion. 170 5250 0 0.07 26 3 3.93 Line of Pits. 171 5280 0 0.12 42 4 3.92 Line corrosion. 172 531 1 0 0.07 24 3 3.92 Line of Pits. 173 5342 0 0.06 21 3 3.91 Line corrosion. 174 5373 0 0.06 22 3 3.92 Line of Pits. 175 5404 0 0.07 28 4 3.92 Line of Pits. 176 5435 0 0.06 23 ' 3.90 Line of Pits. 1 77 5466 0 0.05 20 3 3.92 Line of Pits. 178 5498 0 0.05 19 3 3.93 Shallow ittin . 179 5529 0 0.08 28 4 3.91 Line of Pits. 180 5560 0 0.06 21 3 3.93 Line of Pits. 181 5591 0 0.06 33 3 3.91 Line of Pits. 182 5622 0 0.08 38 3 3.89 Line corrosion. 183 5652 0 0.08 30 3 3.92 Line of Pits. 184 5683 0 0.06 21 3 3.92 Line of Pits. 185 5713 0 0.06 24 3 3.93 Line of Pits. 186 5745 0 0.06 21 ' 3.92 Line of Pits. 187 5775 0 0.07 26 3 3.92 Line corrosion. 188 5806 0 0.07 28 3 3.94 Line of Pits. 189 5837 0 0.09 33 2 3.93 Line of Pits. 190 5868 0 0.06 23 3 3.92 Line corrosion. 191 5899 0 0.05 18 3 3.92 Shallow ittin . 192 5929 0 0.06 ?4 3 3.92 Line of Pits. 193 5960 0 0.06 21 ? 3.92 Line of Pits. Penetration Body Metal Loss Body Page 4 PDS~PORT JOI NT TABI, Pipe: 4.5 in 12.6 ppf L-80 NSCT Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: ~ LATI ON~H EET 1 C-174 Kuparuk CononoPhillips, Alaska inc USA August 9, 2005 Joint No. Jt. Depth (Ft.) Pen. Upset (Ins.) Pen. Body (Ins.) Pen. % Metal Loss "4> Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 194 5991 0 0.08 29 3 3.90 Line corrosion. 195 6022 0 0.06 ?1 ~' 3.92 Line of Pits. 196 6052 0 0.03 13 3 3.93 Shallow ittin . 197 6083 0 0.05 20 ~' 3.92 Line of Pits. 198 6114 0 0.06 24 3 3.92 Line of Pits. 199 6145 0 0.05 18 ? 3.92 Shallow pittin . 200 6175 0 0.04 16 ? _ 3.87 _ Shallow~ttin . 201 6207 0 0.06 23 ? 3.92 - - Line of Pits. 202 6238 0 0.06 23 3 3.91 Line of Pits. 203 6269 0 0.08 30 ? 3.92 Line of Pits. 203.1 6300 0 0 0 0 3.75 DB NIPPLE 204 6301 0 0.07 25 3 3.91 Line corrosion. 205 6332 0 0.05 1 7 3 3.93 ShalloW plttin . 206 6363 0 0.10 38 4 3.92 Line corrosion. 207 6394 0 0.06 22 3 3.91 Line of Pits. 208 6425 0 0.07 25 ' 3.92 Line of Pits. 209 6456 0 0.06 24 3 3.91 Line corrosion. 210 6487 0 0.04 17 3 3.91 Line shallow corrosion. 211 6517 0 0.06 21 ~ 3.93 Line of Pits. 212 6548 0 0.05 18 3 3.93 Shallow ittin . 213 6579 0 0.07 26 4 3.92 Line corrosion. 214 6610 0 0.06 21 4 3.87 Line corrosion. Lt. Deposits, _ Penetration Body Metal Loss Body Page 5 PDS Report Cross Sections .~ `~ „ Well: 1 C-174 Survey Date: August 9, 2005 Field: Kuparuk Tool Type: MFC 40 No 99493 Company: CononoPhillips, Alaska Inc Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin : 4.5 ins 12.6 f L-80 NSCT Anal st: J. Thompson Cross Section for Joint 171 at depth 5302.37 ft Tool speed = 72 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 96 % Tool deviation = 88 ° Finger 21 Penetration = 0.115 ins Line Corrosion 0.12 ins = 42% Wall Penetration HIGH SIDE = UP r1 U ~ Cross Sections page 1 PDS Report Cross Sections C-~ ~~ ,. Well: 1 C-174 Survey Date: August 9, 2005 '~ Field: Kuparuk Tool Type: MFC 40 No 99493 Company: CononoPhillips, Alaska Inc Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin : 4.5 ins 12.6 f L-80 NSCT Anal st: ). Thompson Cross Section for Joint 137 at depth 4258.5 ft Tool speed = 81 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 96 % Tool deviation = 86 ° Finger 22 Penetration = 0.112 ins Line of Pits 0.1 1 ins = 41 % Wall Penetration HIGH SIDE = UP ~~ • Cross Sections page 2 ' ~ ConocoPhillips Alaska, Inc. ' .TUB (0-7( OD:4.', II' ID3.f SURFP (0-71 OD:9.f wtao 'I ' Gas andreUDurt Vah (2504-2`. o~:s.s II ' ~. ' (6300-6c OD:S.E i ' Liner (7035-7C OD:7.E I~ ' SE ~~oaaac oo:s.~ ' Liner (7048-7C OD:7.C ' Liner: pos,-~c OD:6.2 ' Liner F ~~o~o-~c OD:5.5 ' ' LIN (7074-124 OD:S.~ Wt:15. F (7333123 SLOTT LIN Q333-123 OD:5.5 Wt:15. Liner SH ;12483-124 OD55 ~ KRU 1 C-174 ' 1 C-174 API: 500292314000 Well Ty~e: INJ An le TS: de ING SSSV Type: NIPPLE Orig 4/2/2003 Angle aQ TD: 82 deg @ 12485 162, soo Com letion: , ~sa> Annular Fluid: Last W/O: Rev Reason: Show PERFS ~cE Reference Lo : 28' RKB Ref Lo Date: Last U date: 8/2/2005 ~~a, i25 Last Ta : 12391' CTMD TD: 12485 ftKB --- . oo~ Last Ta Date: 10/24/2004 Max Hole An le: 95 de 11151 ~~ ~ Casin Strin - UNDULATING LINER Alternatin 130' Solid Liner w/44' Siotted Liner Sections ,mY Descri~on Size To Bottom ND Wt Grade Thread ~e~ ^ LINER 5.500 _ 7074 12485 12485 15.50 L-80 H dri1511 i05~ ies~ ~ ~ SLOTTED LINER 5.500 7333 12399 3865 15.50 L-80 H dril 511 Casin St~in - ALL STRINGS Descri tion Size To Bottom TVD Wt Grade Thread SURFACE 9.625 0 7174 3726 40.00 L-80 BTC-MD CONDUCTOR 16.000 0 110 110 62.50 H-40 WELDED Tubin Strin - TUBING Size To Bottom TVD Wt Grade Thread NIP ~oi 4.500 0 7062 3711 12.60 L-80 NSCT , ~so~ Perforations Summa Interval ND Zone Status Ft SPF Date T Comment 7333 - 12399 3748 - 3865 WS D,WS 5066 40 3l30/2003 Slotted Altemating 30' slotted liner C,WS Liner wl43' solid liner B.WS C,WS D, WS C,W$ B,W$ NIP -- C, WS ias, D, WS ~50) C,WS B =A~ Gas Lift MandrelsNalves ias, ~~~~ St MD ND Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2504 1920 CAMCO KBG-2 DMY 1.0 BK-5 0.000 0 5/10l2003 Other lu s, e ui ., etc. - JEWELRY x De th TVD ~pe Descrf tion ID o ~si, 23 23 HANGER VETCO GRAY TBG HANGER, MCA TOP CONNECTOR 4.500 ~oo> 499 498 NIP CAMCO'DB' NIPPLE W/NO GO PROFILE 3.812 ~°`°"'"-~ 6300 3544 NIP CAMCO'DB' NIPPLE W/NO GO PROFILE 3.750 7044 3709 SEAL BAKER G-22 LOCATOR SEAL ASSEMBLY 3.870 ~BE ~~o Other lu s, e ui ., etc. - LINER JEWELRY , so> De th ND T e -- Descri don ID ~ 7021 3706 Liner BAKER ZXP PACKER W/HR PROFILE 6.290 PACKER ~~P 7035 3707 Liner NIP RS NIPPLE 6.188 ~~a, 7048 3709 Liner XO CROSSOVER BUSHING 4.890 °0~ 7051 3709 Liner SBE BAKER SEAL BORE EXTENSION 4.750 7070 3712 Liner PUP L-80 HYDRILL 511 SOLID 4.950 12399 3865 Liner BAKER INSERT PACKOFF 0.000 PACKOFF 12483 3876 Liner SHOE WEATHERFORD REAMER SHOE 4.950 IER _ __ _ 85, I00, _ I I - 50) ~erf 99) - ' -~ ~ ~ ED - -- IER 99, - A0, 50) - ~ ~ , _ I ' OE 84, (101 ) **** REEL HEADER **** LDWG 03/04/28 AWS 01 **** TAPE HEADER **** LDWG 03/04/25 01 *** LIS COMMENT RECORD *** ') Q03-Dd7 IJ7/fp ! ! ! !! ! !! ! ! !!! ! ! ! !!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: lC-174 500292314000 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 25-APR-03 MWD RUN 1 MWD RUN 2 MWD RUN 3 1 2 3 F. WENDLER C. WONG J. KINNEY D. WESTER D. GLADDEN D. HEIM MWD RUN 4 MWD RUN 5 MWD RUN 6 4 F. WENDLER F. HERBERT 12 IIN 10E # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 87.20 59.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ) 2ND STRING 3RD STRING 12.250 PRODUCTION STRING 6.750 9.625 7168.0 12485.0 # REMARKS: PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 19' 30.832" LONG: W149 DEG 29' 46.150" LOG MEASURED FROM D.F. AT 87.2 FT. ABOVE PERM. DATUM (M.S.L.). COMMENTS: (1) Baker Hughes INTEQ run 1 utilized Multiple Propagation Resistivity (MPR) and Gamma Ray services from 120 - 3029 feet MD (120 - 2165' TVD). (2) Baker Hughes INTEQ run 2 utilized an AutoTrak RCLS (Rotary Closed Loop System) along with RNT (Reservoir Navigation Tool) Resistivity services from 3029 - 7174 feet MD (2165 - 3748' TVD). (3) Baker Hughes INTEQ runs 3 and 4 utilized an AutoTrak RCLS (Rotary Closed Loop System) along with RNT (Reservoir Navigation Tool) Resistivity and with MAP (Modular Advanced Pressure) services from 7174 - 12485 feet MD (3748 - 3899' TVD). Per CPA request (Mike Warner), the fixed depth of investigation (DOl) resistivity results from the INTEQ post processing routine (NAVTEQ) are included in this LDWG output. NAVTEQ processing was requested and provided over the interval from 7168 - 12455 feet MD. REMARKS: (1) Commenced LWD logging at 140 feet MD (140' TVD). (2) The interval from 2984 to 3029 feet MD (2143 - 2165' TVD) was logged up to 14.8 hours after being drilled due to a trip out of the hole to pick up AutoTrak. Please note that due to the change in Resistivity tools, from MPR to RNT, that the presentation goes from 4 resistivity curves to 2 resistivity curves at 2982' MD ( 2 14 2' TVD). (3) The interval from 7156 to 7174 feet MD (3745 - 3748' TVD) was logged up to 189.6 hours after being drilled due to stuck pipe when tripping after the 12 1/4" hole section. (4) Depth of 9 5/8" Casing Shoe-Logger: 7172 feet MD ( 3748 I TVD) Depth of 9 5/8" Casing Shoe-Driller: 7168 feet MD (3747' TVD) (5) The interval from 9496 to 9527 feet MD (3798 - # $ MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. The curves RS60, RS35, RS20, & RS10 are the fixed depth of investigation (DOI) curves from the NAVTEQ post processing routine. Data is presented only for the interval from 7168 - 10455' MD. MERGE BASE 3029.0 7174.0 9527.0 12485.0 MERGE TOP 66.0 3029.0 7174.0 9527.0 BIT RUN NO 1 2 3 3R # REMARKS: BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- STOP DEPTH 12485.0 START DEPTH 66.0 clipped curves; all bit runs merged. .5000 LDWG File Version 1.000 Extract File: FILE001.HED 50 bytes 132 bytes 116 records... 1 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ *** *** LIS COMMENT RECORD 1024 LDWG .001 **** FILE HEADER **** Minimum record length: Maximum record length: Tape Subfile: 1 $ (6) The interval from 12454 to 12485 feet MD (3894 - 3899' TVD) was not logged due to sensor-bit offset at TD. 3801' TVD) was logged up to 15.8 hours after being drilled due to a trip out of the hole for AutoTrak. ) ) ) *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT lc174 5.xtf 150 ConocoPhillips Alaska, Inc. lC-174 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 RS60 RS60 RES60 0.0 RS35 RS35 RES35 0.0 RS20 RS20 RES20 0.0 RSI0 RSI0 RESI0 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 RS60 TEQ 68 1 OHMM 4 4 7 RS35 TEQ 68 1 OHMM 4 4 8 RS20 TEQ 68 1 OHMM 4 4 9 RSI0 TEQ 68 1 OHMM 4 4 10 ROP MWD 68 1 FPHR 4 4 11 FET MWD 68 1 HR 4 4 12 MTEM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 1308 BOREHOLE CONDITIONS # 12.250 .0 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # TOOL NUMBER SDS 1591 MPR 35083 SRIG 58019 BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. RESIST. GAMMA RAY TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ # .0 60.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: MSB 18704 8.25 MPR MEMORY 3029.0 66.0 2990.0 o 13-MAR-03 STOP DEPTH 2990.0 START DEPTH 66.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 1 .2500 2 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILEOll.HED *** LIS COMMENT RECORD *** 1024 LDWG .002 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 1362 records... Tape Subfile: 2 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 66.000000 12485.000000 0.500000 ) ) ) l MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # ) Spud Mud 9.00 .0 .0 300 .0 .000 .000 .000 .000 64.0 .0 .0 .0 .00 .000 .0 o BIT RUN 1 (MWD Run 1). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1c174.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-174 FN Kuparuk River COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RACLM 0.0 RASL RASL RACSLM 0.0 ) ) RACH RACH RACHM 0.0 RASH RASH RACSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OH:M1:1 4 4 3 RPSL MWD 68 1 OH:M1:1 4 4 4 RPCH MWD 68 1 OH:M1:1 4 4 5 RPSH MWD 68 1 OH:M1:1 4 4 6 RACL MWD 68 1 OH:M1:1 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OH:M1:1 4 4 9 RASH MWD 68 1 OH:M1:1 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 616 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 66.000000 2990.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 715 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 ) ) *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !! !! !!! ! ! ! ! ! ! ! ! ! !!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 log header data for each bit run in separate files. 2 .2500 START DEPTH 2990.0 STOP DEPTH 7157.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAVIGATION TOOL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: BIT RUN 2 (MWD Run 2) . GR/RNT (AutoTrak). CURVE GLOSSARY: 16-MAR-03 MSB 18704 8.25 ATK MEMORY 7174.0 2990.0 7157.0 o 60.5 82.3 TOOL NUMBER ACE 5032Q RNT 2058 RNT 2058 12.250 .0 KCL Polymer 9.60 .0 .0 30000 .0 .000 106.0 .000 .0 .000 .0 .000 .0 .00 .000 .0 o ) GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT lcl74.xtf 150 ConocoPhillips Alaska, I lC-174 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RACLM 0.0 RACH RACH RACHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 TOOL NUMBER SHE 35313 82.3 84.0 MSB 18704 6 . 75 ATK MEMORY 9527.0 7157.0 9496.0 o 26-MAR-03 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DIR DIRECTIONAL # # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9496.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUl1MARY VENDOR TOOL CODE MWD $ START DEPTH 7157.0 log header data for each bit run in separate files. 3 .2500 4 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! !! ! ! !! !! !!! !!!!!!! Extract File: FILE013.HED *** LIS COMMENT RECORD *** 1024 LDWG .004 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 686 records... Tape Subfile: 4 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2990.000000 7157.000000 0.250000 596 Total Data Records: 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 ) BIT RUN 3 (MWD Run 3) . GR/RNT (AutoTrak). CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) NAVTEQ POST PROCESSING RESULTS: RS60 - 60" FIXED DEPTH OF INVEST. RS35 - 35" FIXED DEPTH OF INVEST. RS20 - 20" FIXED DEPTH OF INVEST. RS10 - 10" FIXED DEPTH OF INVEST. $ ) RNT GRAM $ RES. NAVIGATION TOOL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # *** INFORMATION TABLE: CONS MNEM VAL U -------------------------------- WDFN 1c174.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-174 FN Kuparuk River COUN North Slope STAT Alaska RNT 20047 RNT 20047 8.500 7168.0 KCL Polymer 9.05 .0 .0 30000 .0 .000 104.0 .000 .0 .000 .0 .000 .0 .00 .000 .0 o RESIS. RESIS. RESIS. RESIS. (OHMM) (OHMM) (OHMM) (OHMM) .,~ ) *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RACLM 0.0 RACH RACH RACHM 0.0 RS60 RS60 RES60 0.0 RS35 RS35 RES35 0.0 RS20 RS20 RES20 0.0 RSI0 RSI0 RESI0 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Fee~ Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 RS60 TEQ 68 1 OHMM 4 4 7 RS35 TEQ 68 1 OHMM 4 4 8 RS20 TEQ 68 1 OHMM 4 4 9 RSI0 TEQ 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 493 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7157.000000 9496.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 5 593 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes .000 102.0 .000 .0 .000 .0 .000 .0 KCL Polymer 9.15 .0 .0 30000 .0 8.500 7168.0 TOOL NUMBER SHE 17834 RNT 20046 RNT 20046 82.3 84.0 MSB 18704 6.75 ATK MEMORY 12485.0 9496.0 12485.0 o 29-MAR-03 NEUTRON TOOL # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOTTOM) TOOL TYPE DIRECTIONAL RES. NAVIGATION TOOL GAMMA RAY TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ # # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12485.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ START DEPTH 9496.0 log header data for each bit run in separate files. 4 .2500 5 !!!!!!!! ! ! ! !! !! !!!! LDWG File Version 1.000 !!!!!!!!! ! ! !! !!!!!! Extract File: FILE014.HED *** LIS COMMENT RECORD *** 1024 LDWG .005 **** FILE HEADER **** I~ i '} MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 3R (MWD Run 4). GR/RNT (AutoTrak). CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) NAVTEQ POST PROCESSING RESULTS: RS60 - 60" FIXED DEPTH OF INVEST. RESIS. (OHMM) RS35 - 35" FIXED DEPTH OF INVEST. RESIS. (OHMM) RS20 - 20" FIXED DEPTH OF INVEST. RESIS. (OHMM) RS10 - 10" FIXED DEPTH OF INVEST. RESIS. (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT lc174.xtf 150 ConocoPhillips Alaska, I lC-174 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL RPCH RACL RACH RS60 RS35 RS20 RS10 ROPS RPTH TCDM GRAM RPCL RPCH RACL RACH RS60 RS35 RS20 RS10 ROPS RPTH TCDM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 GRAM RPD RPS RACLM RACHM RES60 RES35 RES20 RES10 ROPS RPTHM TCDM * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet \ Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= O) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 RS60 TEQ 68 1 OHMM 4 4 7 RS35 TEQ 68 1 OHMM 4 4 8 RS20 TEQ 68 1 OHMM 4 4 9 RSI0 TEQ 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 630 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 9496.000000 12485.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 6 730 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 03/04/25 01 **** REEL TRAILER **** LDWG 03/04/28 AWS 01 Tape Subfile: 7 Minimum record length: Maximum record length: '\ } 2 records... 132 bytes 132 bytes